{"vendor":"ESRI","LayerId":254,"LayerName":"Wellbore - History","type":"FeatureCollection","fields":[{"name":"OBJECTID","type":"esriFieldTypeOID"},{"name":"wlbNpdidWellbore","type":"esriFieldTypeInteger"},{"name":"wlbName","type":"esriFieldTypeString","length":40},{"name":"wlbHistory","type":"esriFieldTypeString","length":2048},{"name":"wlbHistoryDateUpdated","type":"esriFieldTypeDate","length":8}],"features":[{"type":"Feature","id":"1","properties":{"OBJECTID":1,"wlbNpdidWellbore":2,"wlbName":"1/3-4","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 1/3-4 was drilled on the\r\nnorthern part of the Hidra High in the North Sea. The objective was to test the\r\nhydrocarbon potential of the Danian and late Cretaceous Chalk, on a domal structure\r\ninduced by halokinesis.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 1/3-4 was spudded with the\r\nsemi-submersible installation Dyvi Alpha on 15 February 1983 and drilled to TD\r\nat 3198 m in the Late Permian Zechstein Group. While drilling through Middle\r\nMiocene claystones, the average background gas increased rapidly from 5% to 80%\r\nbetween 1580 m and 1595 m and, at this depth, the mud weight had to be\r\nincreased gradually from 1.37 to 1.50 - 1.53 to lower the gas content. Furthermore,\r\nto stop the gas leakage and to isolate the weak zone, it was decided to set the\r\n13 3/8" casing. Logs were run (ISF/BHC and LDT/CNL) and the casing was set\r\nwith shoe at 1557 m. While circulating after the logging a gain of 1 m3 with\r\ngas and more than 100 litres of oil occurred. To stabilize the well, 2 cement\r\nplugs and 4 barite plugs were set, in order to stop the gas leaking from the\r\nformation. In total, twenty days were spent on circulating, logging (ISF/BHC\r\nand LDT/CNL), setting the 13 3/8" casing, and plugging before drilling of\r\nthe 12 1/4" section commenced. While drilling the 12 1/4" hole, the\r\nbackground gas varied between 32 and 84% down to 1695 m where the mud-weight\r\nwas raised to 1.60. The background gas then decreased between 10 and 25% and\r\ndrilling continued normally. Logs performed at the end of the 12 1/4"\r\nphase and covering the zone of interest are strongly affected by large cavings\r\nand by barite squeezed into the formation. Side wall core recovery was very\r\npoor from the caved zone. The well was drilled water based.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe first ev","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"2","properties":{"OBJECTID":2,"wlbNpdidWellbore":3,"wlbName":"2/2-3","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThe wildcat 2/2-3 was drilled on a domal\r\nstructure, south of the Ula-Gyda fault zone. Main objective was Late Jurassic\r\nsandstone in the Vestland Group. Secondary target was Middle Jurassic and Late\r\nTriassic sandstones. \u003c/p\u003e\r\n\r\n\u003cp\u003eAccording to the license agreement the\r\nwell should be drilled into the Triassic, salt, or a maximum depth of 5000 m\r\nwhatever came first\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was spudded with the\r\nsemi-submersible rig Treasure Saga on 4 February 1983 and drilled to TD at 4100\r\nm, 170 m into the Triassic Smith Bank Formation. At 3286 m the string was lost\r\nafter a wiper trip. The well had to be plugged back to 3053 m and sidetracked\r\nfrom this point. At 3420 m the string was again lost but was recovered. The\r\nwell was drilled using water-based mud. The well was drilled with seawater and\r\nbentonite down to 655 m, with polymer/gypsum/"SST 202" mud from 655 m\r\nto 1910 m, with lignite/Drispac/gypsum mud from 1910 m to 3523 m, and with\r\nlignite/lignosulphonate mud from 3523 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well penetrated 2998 m of Cenozoic\r\nsediments represented by the Nordland, Hordaland and Rogaland Groups. The\r\nsequence was mainly composed of argillaceous deposits. The Oligocene Sand Unit\r\n(Vade Formation) recognized in well 2/2-1 and 2/2-2, was not established in\r\nthis well. The Cretaceous sequence consisted of two lithostratgraphic units,\r\nthe Chalk and Cromer Knoll Group. They were separated by an unconformity\r\nranging from Santonian to Middle Albian. The Early Cretaceous and upper part of\r\nthe Late Jurassic (Ryazanian-Middle Volgian) are highly condensed. The Late\r\nJurassic predominantly consists of claystones of the Mandal (4m) and Farsund\r\nFormations. The Ula Formation is present from 3880 m in the bottom part of the\r\nLate Jurassic as a sandstone sequence of Early Kimmeridgian - Late Oxfordian\r\nage. The formation is resting unconformably on sediments of the Triassic Group.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe Shetland Group chalk, 2965 m to 3494\r\nm, has ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"3","properties":{"OBJECTID":3,"wlbNpdidWellbore":4,"wlbName":"30/6-12","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThe appraisal well 30/6-12 was drilled in\r\na down flank position on the Alpha block east of the 30/6-1 Oseberg Discovery\r\nwell, which tested gas in the Middle Jurassic Brent Group. The main objectives\r\nof the well were to confirm the reserves of hydrocarbons, to prove oil in the\r\nEtive Formation, to define and refine the geological model for the Alpha\r\nstructure, to obtain core from the Brent Group, and to do a water injection\r\ntest in the oil zone. The well was planned to be drilled 50 m into the Drake\r\nFormation to a total depth of 2764+/- 50 m.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 30/6-12 was spudded with the semi-submersible\r\ninstallation Treasure Seeker on 20 February 1983. Drilling operations went\r\nwithout significant problems down to 615 m. The 20" casing was set with\r\nshoe at 600 m. During the subsequent landing of the BOP on the well head, the\r\nball joint parted, and the BOP fell down on the wellhead. The wellhead was so\r\nbadly damaged that the well had to be abandoned: Final TD of the well thus\r\nbecame 615 m in Pliocene sediments; prospective depth was not reached.\u003c/p\u003e\r\n\r\n\u003cp\u003eTop Pliocene was encountered at 350 m.\u003c/p\u003e\r\n\r\n\u003cp\u003eNo cores were cut and no wire line fluid\r\nsamples were taken.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 9 March 1983 as a junk well. Replacement well 30/6-13 was spudded two days later on a\r\nlocation ca 40 m to the south-west of 30/6-12\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was performed.\u003c/p\u003e\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"4","properties":{"OBJECTID":4,"wlbNpdidWellbore":5,"wlbName":"34/10-17","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 34/10-17 was the first well drilled\r\non the Beta structure in the SE segment of block 34/10, south-west of the\r\nAlpha-structure, which contained the Gullfaks Sør Field. The primary objective\r\nof the well was to evaluate possible hydrocarbon accumulations in the Middle\r\nJurassic Brent sandstones. The secondary objectives were the Early Jurassic\r\nDunlin and Statfjord sandstones.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 34/10-17 was spudded with\r\nthe semi-submersible installation Deepsea Bergen on 22 February 1983 and\r\ndrilled to TD at 3466 m in the Early Jurassic Statfjord Formation. The well was\r\ndrilled down to 2687 m without special drilling problems. At 2687 m a heavy\r\nflow was observed after a drilling break. The well was shut in, and due to a\r\nplugged cement hose and kill line failsafe valve, about 200 hours were used to\r\ncirculate out the influx, stabilize, clean up and condition the hole. Further technical\r\nfailure and tight hole caused extensive time logging the 6" section, and\r\nthe logging programme was reduced. The well was drilled with Seawater/gel spud\r\nmud down to 668 m and with seawater/gel/Lignosulphonate mud from 668 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe Brent Group was encountered at 2685 m\r\nwith hydrocarbon bearing sandstones in the Tarbert and Ness Formations. FMT\r\npressures indicated a gas/oil contact at ca 2862 m, and an oil/water contact at\r\nca 2914 m in the lower part of the Ness Formation. The logs indicated a total oil\r\nand gas net pay of 122.5 m with average porosity 22.5% and average water\r\nsaturation 27%. Also the underlying water bearing Etive and Rannoch Formations of\r\nthe Brent Group had good reservoir quality sandstones. The Dunlin and Statfjord\r\nsandstones were water bearing. Shows were recorded on cores down to 2947.5 m in\r\nthe Ranno","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"5","properties":{"OBJECTID":5,"wlbNpdidWellbore":6,"wlbName":"31/2-11","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 31/2-11 was drilled as an appraisal\r\nwell in the Troll West oil province in the Northern North Sea. The main\r\nobjectives were to appraise the reservoir quality and the extension of the 28-m\r\noil column in the southern part of the 31/2-7 accumulation in the Viking Group\r\nreservoir sequence. The well would assist in the mapping of the permeability\r\ndistribution in the oil province, provide an additional data point for the\r\ncorrelation and mapping of the depositional units, and obtain additional oil\r\nproduction test data for input to the field development. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 31/2-11 was spudded with the semi-submersible\r\ninstallation Borgny Dolphin on 17 March 1983 and drilled to TD at 1744 m in the\r\nMiddle Jurassic Fensfjord Formation. No major problems occurred during\r\ndrilling. The well was drilled with Seawater and gel down to 810 m, with\r\nKCl/polymer mud from 810 m to 1535 m, and with CaCl2/CaCO3/polymer mud from\r\n1535 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eTop Jurassic, Sognefjord Formation, was\r\nencountered at 1558 m. The reservoir sands were found to be hydrocarbon bearing\r\nwith GOC at 1566 m (1541 m sub-sea) and OWC (50% saturation) at 1593 m (1567 m sub-sea),\r\nin-line with the regional contacts in this area of the Troll West Oil Province.\r\nBelow OWC residual oil was interpreted down to some 1640 m.\u003c/p\u003e\r\n\r\n\u003cp\u003eA total of eight cores were cut. To\r\nenable investigation of the shallow sediments, 2 cores were cut in the interval\r\n380 m to 399 m and one from 475 to 476 m. Five cores were cut in the Late\r\nJurassic reservoir sands from 1555 to 1629 m using fibre glass sleeve\r\ntechniques to achieve better recovery in the poorly consolidated sands. Attempts\r\nto obtain RFT fluid samples were unsuccessful due to plugging of the tool with\r\nchalk particles from the mud.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 25 May 1983 as an oil and gas appraisal.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eTwo DST's were performed, one in the\r\nwater zone and one in the oil zone. DST 1","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"6","properties":{"OBJECTID":6,"wlbNpdidWellbore":7,"wlbName":"30/6-13","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 30/6-13 is a replacement for the\r\n30/6-12 well, which was terminated in Pliocene sediments due to technical\r\nproblems. The appraisal well 30/6-13 was drilled in a down flank position on\r\nthe Alpha block east of the 30/6-1 Oseberg Discovery well, which tested gas in\r\nthe Middle Jurassic Brent Group. The main objectives of the well were to\r\nconfirm the reserves of hydrocarbons, to prove oil in the Etive Formation, to\r\ndefine and refine the geological model for the Alpha structure, to obtain core\r\nfrom the Brent Group, and to do a water injection test in the oil zone. The\r\nwell was planned to be drilled 50 m into the Drake Formation to a total depth\r\nof 2764+/- 50 m. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 30/6-13 was spudded with the semi-submersible\r\ninstallation Treasure Seeker on a location ca 40 m to the south-east of well\r\n30/6-12, on 11 March 1983. It was drilled to TD at 2775 m in the Early Jurassic\r\nDrake Formation. No major problems occurred during drilling. The well was\r\ndrilled with spud mud down to 613 m and with a KCl/polymer mud from 613 m to TD.\r\nA pill of Imco-spot/Pipelax 140 bbl pill with 50 bbl diesel was spotted from\r\n1410 m to 1525 m to free the 13 3/8" casing, which was stuck. The casing\r\ngot free and was cemented with shoe at 1705 m.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well encountered hydrocarbons from\r\n2571 to 2671 m in the Middle Jurassic Brent Group sandstones. No other\r\nhydrocarbon bearing reservoirs were encountered. Oil shows reported from\r\nlimestone stringers in the interval 2120 - 2325 m in the Paleocene and Late\r\nCretaceous were considered uninteresting.\u003c/p\u003e\r\n\r\n\u003cp\u003eA total of nine cores were cut\r\ncontinuously from the Ness Formation to the Dunlin Group shales. One successful\r\nsegregated RFT fluid sample was obtained at 2661.5 m (3 l oil and 0.57 Sm3 gas).\r\n\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 14 May 1983 as an oil/gas appraisal well.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThree DST's were performed in the Brent\r\nGroup. \u003c/p\u003e\r\n\r\n\u003cp\u003eDST 1 was a co","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"7","properties":{"OBJECTID":7,"wlbNpdidWellbore":8,"wlbName":"7120/12-3","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 7120/12-3 is located in the Hammerfest Basin, south of the Snøhvit area. The primary objective was to test a sandstone\r\nreservoir of Middle to Early Jurassic age on a structure (Alke North) separate\r\nfrom the Alke Structure tested in well 7120/12-1 and 7120/12-2. A secondary\r\nobjective was to test Middle Triassic sandstones, providing the Jurassic\r\nreservoir proved a gas column greater than 60 m. The well was planned to be\r\ndrilled to 2498 + 30 m or to 3312 +100 m if the Jurassic test was positive.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 7120/12-3 was spudded with\r\nthe semi-submersible installation on 16 March 1983 and drilled to TD at 2523 m\r\nin the Late Triassic Fruholmen Formation. Swelling shales and some tight hole\r\nproblems occurred in the 17 1/2" section; otherwise no significant\r\nproblems were encountered during drilling. The well was drilled using seawater\r\n/ bentonite / hi-vis pills down to 605 m and with a gypsum / polymer mud from\r\n605 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe Middle to Early Jurassic sandstone\r\nreservoir was found gas bearing from 2157.5 to 2182.5 m (upper part of Stø\r\nFormation) where the gas/water contact was established. The reservoir consisted\r\nof very fine to fine, relatively homogeneous and clean sandstones made up of\r\nclear quartz with traces of mica, glauconite and carbonaceous material. From\r\nwire line logs the net pay was calculated to be 24 m, with an average porosity\r\nof 17 % and an average water saturation of 17 %. Traces of very weak shows were\r\ndescribed from cuttings and sidewall cores between 1945 m to\u00A0 2148.5 m in\r\nshales of the Late Jurassic\u00A0 Hekkingen and Fuglen Formation, reflecting the\r\nhigh organic content of these shales. Direct shows were only seen in the lower\r\npart of the gas-bearing reservoir from 2170 m to 2182.5 m. They appeared on\r\nsandstones as traces of dull yellow fluorescence with weak slow streaming dull\r\nyellow to white crush cut, no stain or residue were detected. Very weak shows\r\nwere detected in shale","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"8","properties":{"OBJECTID":8,"wlbNpdidWellbore":9,"wlbName":"7120/8-3","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThe purpose of appraisal well 7120/8-3\r\nwas to test the extension of the Askeladden North structure in the northeast\r\ndirection. The primary target was sandstones of Early to Middle Jurassic age.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was spudded with the\r\nsemi-submersible rig West Vanguard on 7 April 1983 and drilled to TD at 2335 in\r\nEarly Jurassic rocks of the Nordmela Formation. Two cores were cut in the Middle to\r\nLower Jurassic sequence. No major problems occurred during drilling. The well was\r\ndrilled water based with spud mud down to 671 m and with gypsum/polymer mud\r\nfrom 671 m to TD. \u003c/p\u003e\r\n\r\n\u003cp\u003eShows were recorded on cores and cuttings\r\nover the interval 2192 m to 2286 m. The Jurassic reservoir interval was found\r\nto be below the gas/water contact known from well 7120/8-1, and thus water\r\nbearing. Two cores were cut in the interval 2198 m to 2234.8 m. No fluid\r\nsamples were taken.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 24\r\nMay 1983 as a dry well.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was performed\u003c/p\u003e\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"9","properties":{"OBJECTID":9,"wlbNpdidWellbore":10,"wlbName":"30/3-3","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 30/3-3 was drilled on the Lomre\r\nTerrace between the Veslefrikk and Brage oil fields. The primary objective was\r\nsandstone of the Middle Jurassic Brent Group, the secondary objective was\r\nsandstone of the Early Jurassic Dunlin Group.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 30/3-3 was spudded with the\r\nsemi-submersible installation Ross Isle on 2 April 1983 and drilled to TD at 3419\r\nm in the Early Jurassic Statfjord Formation. No significant problem was\r\nencountered in the operations. The well was drilled with spud mud down to 969\r\nm, with gypsum/lignosulphonate/CMC from 969 m to 2861 m, and\r\ngel/lignosulphonate/CMC from 2861 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was dry. Oil shows were described\r\non sandstone cuttings from 3035 - 3037 m in the uppermost Etive Formation and\r\nfrom 3185 m to TD. Sandstone side wall cores from the same interval had no\r\nshows, and geochemical extracts proved only immature hydrocarbons from in-situ\r\nshales.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eOne core was cut in the Ness Formation\r\nfrom 2979 m to 2992.5 m. No wire line fluid samples were taken.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was permanently abandoned on 30\r\nMay 1983 as a dry well.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eTesting\u003c/span\u003e\u003c/b\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo drill stem test was performed. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"10","properties":{"OBJECTID":10,"wlbNpdidWellbore":11,"wlbName":"30/9-2","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThe wildcat 30/9-2\r\nwas planned as the first well on the Gamma structure in block 30/9. Well 30/6-9\r\nhad previously penetrated the structure but this well failed to encounter the\r\noil/water contact. The primary objectives of 30/9-2 were to verify the reserve\r\nestimate for the main part of the gamma structure and penetrate the oil/water\r\ncontact in the lower part of the Brent Group. Additional objectives were to\r\nobtain core material from the oil zone in the Etive Formation and perform a\r\nwater injection test in this, obtain information on the quality of the\r\nreservoir in the water zone and stratigraphical information on the southern\r\npart of the Gamma structure.& The well\r\nwas temporarily abandoned for about one year and then re-entered for an\r\nextended test.\u003c/p\u003e\r\n\r\n\u003cp\u003e \u003c/p\u003e\r\n\r\n\u003cp\u003e \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 30/9-2\r\nwas spudded with the semi-submersible installation \"Nortrym\" on 1\r\nApril 1983 and drilled to a total depth of 2830 m in the Early Jurassic Dunlin\r\nGroup. The well was drilled using water-based mud down to the 12 1/4\" hole\r\nat 1715 m. The 12 1/4\" hole was drilled to TD using oil based mud\r\n(\"ENVIROMUL\" and \"IL 2832 oil\" as oil base). While running\r\nthe 13 3/8\" casing, this got stuck at 1334 m. The casing was worked free\r\nusing diesel in the mud and the casing was set at 1680 m. After drilling the 12\r\n1/4\" hole to 2203 m the drill pipe got stuck with the bit at 2170 m.\r\nSeveral unsuccessful attempts were made to free the pipe. The drill pipe was\r\nthen backed off and the well was cemented back and sidetracked from 1482.5 m. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe Brent Group\r\nsandstones (2578-2767 m) RKB were hydrocarbon bearing down to 2737m where an\r\noil/water contact was encountered within the Etive Formation sandstones\r\n(2698-2767m).& No additional hydrocarbon\r\nbearing reservoirs were encountered by this well. Poor hydrocarbon shows\r\nreported from Upper Cretaceous limestones were considered uninteresting. The\r\nNess Formation (2578-2698 m) consisted of","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"11","properties":{"OBJECTID":11,"wlbNpdidWellbore":12,"wlbName":"6610/7-1","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 6610/7-1 is located in the Helgeland\r\nBasin outside Mid Norway and was drilled on a tilted fault block in the\r\nsoutheastern corner of the block. The purpose of this wildcat well was\r\nprimarily to gather information about the hydrocarbon potential and\r\nstratigraphy of the Helgeland Basin. The main targets were sandstones of Middle\r\nto Lower Jurassic age. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe well is Reference Well for the Ror\r\nFormation.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 6610/7-1 was spudded with\r\nthe semi-submersible installation Nordraug on 18 April 1983 and drilled to TD\r\nat 3333 m in the Late Triassic sediments Red Beds. Operations were interrupted\r\nby a 10.5 days seamen's strike. No serious technical problems occurred during\r\ndrilling. The well was drilled to 815 m using spud mud. From 815 m to 2115 m\r\nthe well was drilled with gypsum/lignosulphonate mud, and from 2115 m to TD\r\nwith gel/lignosulphonate/lignite mud. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was water bearing but\r\nhydrocarbon shows were observed on cores and cuttings in Early Jurassic\r\nsandstone beds from 2656 m to 2715 m. The Spekk Formation from 2271 m to 2315 m\r\nis a good to rich source rock with around 9 % TOC and potential for gas and\r\noil. It is more gas-prone in the lower part. It has reached early oil window\r\nmaturity in well position. The Åre Formation consists mainly of low-TOC sand\r\nwith abundant seams of coals, carbargillites and organic-rich shales. The\r\ncoals/carbargillites have TOC contents ranging 37 - 59 % and are quite\r\nliptinitic, containing kerogen type II/III-III with good potential for oil and\r\ngas generation locally and a rich overall potential for gas.\u003c/p\u003e\r\n\r\n\u003cp\u003eFour cores were cut, one from the Early\r\nCretaceous sequence and three from the Early Jurassic sands. A segregated\r\nsample was taken at 2748 m. It contained mud filtrate.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 19\r\nJune 1983 as a dry hole with oil shows in Early Jurassic sandstone.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"12","properties":{"OBJECTID":12,"wlbNpdidWellbore":13,"wlbName":"7117/9-2","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eExploration well 7117/9-2 is located on\r\nthe Senja Ridge west of the Tromsø Basin. The primary objective of wildcat\r\n7117/9-2 was to test sandstone or limestone reservoirs of Early Cretaceous age\r\nin a well-defined offset bounded structure within the Senja Ridge (the Lom\r\nstructure). An alternative model suggested that the primary objective was\r\nsandstones of Middle Jurassic age and the secondary objectives were sandstone\r\nreservoirs of Triassic age or older. The well was planned to be drilled to a\r\ntotal depth of 5000 m and serve as the deep commitment well on the block.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003e7117/9-2 was spudded with the\r\nsemi-submersible installation Treasure Scout on 7 May 1983 and drilled to a\r\ntotal depth of 5000 m in Early Cretaceous (?Aptian) clay stone. Nineteen rig\r\ndays were lost due to strike, otherwise no major problems occurred during\r\ndrilling of this well. The well was drilled with seawater and hi-vis pills down\r\nto 358 m. with seawater and bentonite from 358 m to 915 m, and with gypsum /\r\npolymer from 915 m to 2500 m. From 2500 m the mud was dispersed to a\r\nlignosulphonate mud, which was used for the remaining well down to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003ePleistocene deposits were encountered\r\ndown to 400 m and underlain by a thick sequence of Pliocene clays down to 1092\r\nm. Paleocene rocks continued down to 1345 m followed by a thin sequence of\r\nCampanian (1380 m to1396 m) and Late Albian to Early Cenomanian (1400? - 1410)\r\ndeposits. The lowermost strata penetrated by the well consisted of a thick,\r\npoorly defined sequence of claystones. The upper sequence from 1625 m to 3440 m\r\nis of Albian to Aptian age. In the lower section, few identifiable fossils were\r\nrecorded and preservation was poor. The Lom structure was penetrated in a down\r\nflank position at approximately 3375 m. The structure proved to consist of\r\nEarly Cretaceous silty claystones of probable Aptian age and bounded by\r\nfractured dolomites. No rocks with reservoir properties were encountered in","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"13","properties":{"OBJECTID":13,"wlbNpdidWellbore":14,"wlbName":"31/2-12","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 31/2-12 was drilled as an appraisal well in the Troll\r\nWest oil province in the Northern North Sea. The main\r\nobjectives were to evaluate various techniques for gas production wells in the\r\nTroll field, to establish the reservoir quality in the central part of the\r\nTroll field gas accumulation, and to provide additional data point for the\r\ncorrelation and mapping of the depositional units.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 31/2-12 was\r\nspudded with the semi-submersible installation Borgny Dolphin on 26 May 1983 and drilled to TD at 1615 m in the Middle Jurassic Fensfjord Formation. On 4\r\nJune, after running the BOP-stack, operations were interrupted by a labour\r\ndispute. After the strike ended on 17 June problems with the BOP lead to a further\r\n4 days delay before normal drilling operations were resumed. Some instability\r\nproblems and well kicks were encountered while drilling and testing in the\r\nreservoir. The well was drilled with Seawater and gel down to 807 m, with\r\nKCl/polymer mud from 807 m to 1338 m, and with CaCl2/CaCO3/polymer mud from\r\n1338 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eTop reservoir in well 31/2-12 was\r\nencountered at 1365 m. The formations were interpreted to be gas bearing all\r\nthrough the Sognefjord Formation, the Heather Formation (1487 - 1541 m), and down\r\nto a clear GOC at 1570.5 m in the Fensfjord Formation. The upper part of the Sognefjord\r\nFormation consisted of generally clean sandstones. Below 1455 m the sands were\r\nmicaceous and silty. Tight calcareous streaks occurred over the whole section.\r\nOil was interpreted from 1570.5 m down to 1581.0 m, where an abrupt drop in\r\nresistivity was interpreted as the oil/water contact. The contact was somewhat\r\nobscured however by a change in lithology from clean, but rather tight,\r\nsandstone to micaceous sandstone. No movable oil was calculated below this\r\ndepth, but shows (fluorescence and cut) was observed on sidewall cores down to\r\n1608 m.\u003c/p\u003e\r\n\r\n\u003cp\u003eTen cores were cut in the Late Jurassic Sognefjord\r\nreservo","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"14","properties":{"OBJECTID":14,"wlbNpdidWellbore":15,"wlbName":"6609/11-1","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 6609/11-1 was drilled on the\r\nNorthwestern side of the Helgeland Basin outside Mid Norway. The primary\r\nobjective was to test sandstone reservoirs of Middle to Early Jurassic age in a\r\nstructurally high position on a narrow SW-NE trending horst block. The\r\nsecondary objective was to test sandstone reservoirs of Early Jurassic to Upper\r\nTriassic age. The well was planned to be drilled to 3200 m, 200 m into the\r\nTriassic.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 6609/11-1 was spudded with\r\nthe semi-submersible installation Treasure Seeker on 19 May 1983 and drilled to\r\nTD at 3068 m in Late Triassic sediments of the Åre Formation. No major\r\ntechnical problems occurred during drilling. Operations were interrupted for 11\r\nand a half days due to a crew strike. The well was drilled with seawater and\r\nhi-vis pills to 915 m and with gypsum/polymer mud from 915 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well encountered good quality\r\nsandstone reservoirs of Early Jurassic and Late Triassic age. These reservoirs\r\nwere water bearing with minor amounts of residual hydrocarbons indicated on the\r\nlogs. The uppermost part of the sandstone interval, 2546 - 2570 m had the\r\nhighest reservoir quality encountered in the well. Porosities ranged from\r\n15-30% (20.6% average in net sand) with a net/gross sand ratio of 0.85 and an\r\naverage SW of 90%. The unit ranged from Sinemurian to Pliensbachian in age and\r\nconsisted of massive to thinly bedded, very fine to fine grained sandstones\r\nwith interbeds and stringers of shale, siltstone and limestone. Below 2570 m\r\nthe sandstone units tended generally coarser grained and exhibited fining\r\nupward sequences with reduced porosity and net/gross ratio. The only recorded\r\noil show in the well was on core no 1 at 2559.7 m to 2560.9 m. No significant\r\nmud gas levels were recorded. The Late Jurassic shales and the Early Jurassic\r\ncoals and carbonaceous shales are rich source rocks for oil and gas. However,\r\nthe Late Jurassic shales are immature in the well","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"15","properties":{"OBJECTID":15,"wlbNpdidWellbore":16,"wlbName":"6407/2-2","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 6407/2-2 is located east on the\r\nHalten Terrace off shore Mid Norway. The well tested the southern (Gamma) fault\r\ncompartment of a horst with true vertical closure below the base Cretaceous\r\nlevel. The gas/condensate discovery well 6507/11-1 was located on the northern\r\n(Alpha) compartment of the same structure. The primary target of the well was\r\nthe middle Jurassic sandstone; secondary target was Early Jurassic sandstone. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe well is Reference Well for the Melke\r\nFormation.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 6407/2-2 was spudded with\r\nthe semi-submersible installation Treasure Saga on 17 May 1983 and drilled to\r\nTD at 3351 m, 71 m into the Triassic Grey Beds. After drilling the 26"\r\nhole the well was observed flowing and the mud weight was corrected. No other\r\nmajor problems occurred during drilling. After having drilled out of 13\r\n3/8" casing shoe a cement plug was set from 1960 m - 1995 m, and one from\r\n340 m - 400 m, due to temporarily plugging and abandonment of the well caused\r\nby strike The strike was efficient (no drilling progress was obtained) for 13\r\ndays, from June 6th to June 19th. The well was drilled with spud mud down to\r\n865 m, with gypsum/polymer mud from 865 m to 1995 m, and with lignosulphonate\r\nmud from 1995 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well proved mainly claystones down to\r\nthe Middle Jurassic Sandstone. The Cainozoic with a total thickness of 1809 m\r\noverlies the Late Cretaceous where the topmost Maastrichtian is missing. Two\r\nhundred and forty meter of Late Cretaceous and 81.5 m of Early Cretaceous is\r\npreserved, separated by an unconformity ranging in age from Middle Santonian to\r\nAlbian. High gas readings were experienced in the upper part of the Cretaceous\r\ntogether with heavier hydrocarbons detected for the first time in the well. A\r\nstudy of wire line logs, sidewalls cores and hole response indicate that the\r\ngas was overpressured, and trapped in a non-reservoir lithology. Base\r\nCretaceous unconformity was en","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"16","properties":{"OBJECTID":16,"wlbNpdidWellbore":17,"wlbName":"7119/12-3","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThe primary objective of wildcat\r\n7119/12-3 was to test possible hydrocarbon accumulations in sandstones of\r\nMiddle to Lower Jurassic age. Gas and condensate were discovered in the\r\nsandstone sequences. Planned TD was 3765 m.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eExploration well 7119/12-3 was spudded\r\nwith the semi-submersible installation Dyvi Delta on 20 may 1982 and drilled to\r\nTD at 3314 m in the Early Jurassic Nordmela Formation. A total of 121 days was\r\nspent on this well including testing and a 9.5 days seamen's strike. The time\r\nestimate was 106 days. No major problems occurred due to drilling. The well was\r\ndrilled using spud mud down to 303 m, with gel/seawater from 303 m to 716 m,\r\nwith gypsum/polymer from 716 m to 1618 m, and with gel/lignosulphonate from\r\n1618 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eHydrocarbon accumulations were discovered\r\nin sandstone sequences between 3144 - 3285 m in the Stø Formation. From log\r\nevaluation the interval contained 118 m net sand. The gas/water contact at 3285\r\nm is based on the log evaluation. Due to very tight and hard formation only two\r\nRFT pressure points were obtained out of 16 attempts (seal failures). Organic\r\ngeochemical analyses found only poor source rock potential in the well. Shales\r\nin the Late Jurassic Hekkingen Formation from 3026 m to 3107 m had high TOC\r\nlevels in the range 3% to 9%. However, with Hydrogen Indexes only in the range\r\n30 - 40 mg HC/g TOC in non-caved, high-TOC samples, these shales are gas prone,\r\nand can not produce any significant quantities of liquid hydrocarbons. The well\r\nis immature down to ca 2300 m and reaches oil window maturity at ca 3000 m.\r\nThree cores were cut in the sandstones of the Middle to Early Jurassic Stø\r\nFormation. The two first were cut in the interval 3145 m to 3154.85 m with 100\r\n% recovery. The third was cut from 3250 m to 3267 m with 97 % recovery. One RFT\r\nsegregated sample was taken at 3187 m. The 2 3/4 -gallon chamber was bled off\r\non the rig. It had an opening pressure of 38.9 ba","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"17","properties":{"OBJECTID":17,"wlbNpdidWellbore":18,"wlbName":"7120/7-2","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 7120/7-2 is located in the Snøhvit\r\nField area. The primary of the well was to test possible hydrocarbon\r\naccumulations in sandstones of Middle to Early Jurassic age. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 7120/7-2 was spudded with\r\nthe semi-submersible rig West Vanguard on 26 May 1983 and drilled to TD at 2523\r\nm, 5 meters into Late Triassic rocks. Due to boulders at the spud location the\r\nrig was moved 11 m north and respudded. A sand body with shallow gas was\r\nencountered at 378 m to 382.5 m and it was decided to set the 20" casing\r\nshoe above this sand. After setting this casing the rig was shut down due to\r\nstrike from 3 June at 2400 hrs to 18 June at 1125 hrs. The well was drilled\r\nusing gel mud down to 815 m, with gypsum/polymer mud from 815 m to 1515, and\r\ndispersed to a lignosulphonate (Unical) mud from 1515 m to TD. \u003c/p\u003e\r\n\r\n\u003cp\u003eHydrocarbon accumulations were discovered\r\nin the Middle Jurassic Stø Formation sandstone sequence from 2149.5 m down to a\r\ngas/water contact at 2228 m. Shows were recorded below 1809 m in the Cretaceous\r\nKolje Formation. Organic geochemical analyses showed that TOC increases down\r\nthrough the Cretaceous, but generally the Cretaceous mudstones were regarded as\r\nimmature, poor source rocks with a primary potential for gas. Entering into the\r\nsilty shales and mudstones of the Late Jurassic Hekkingen Formation at 2107 m\r\nTOC increases abruptly above 3%. TOC continues to increase to 9 % at the base\r\nof the Hekkingen Formation. These shales are potentially very good source rocks\r\nfor gas and condensate above ca 2120 metres and rich sources for light oil and\r\ngas below this depth. Maturity evaluation was difficult due to reworked\r\nmaterial and cavings, but most likely the well is immature all through,\r\npossibly marginally mature below ca 2000 m. Five cores were cut in the\r\nsandstones from 2168 m to 2244 m. Four RFT samples were taken. Sample 1 was\r\ntaken at 2150 m (gas, mud filtrate and film of condensate), sample 2 at 2","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"18","properties":{"OBJECTID":18,"wlbNpdidWellbore":19,"wlbName":"6609/7-1","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 6609/7-1 is located in the\r\nNordland I area outside mid Norway. The objective was to test anticipated Late\r\nPaleozoic sandstones within the Nordland Ridge. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 6609/7-1 was spudded with\r\nthe semi-submersible installation Nordraug on 21 June 1983 and drilled to TD at\r\n1969 m in Pre-Devonian Basement. Mud problems occurred several times during\r\ndrilling, well flowing and lost circulations occurred from 1500 m to TD. The\r\nwell was drilled using Seawater/gel down to 1025 m and with\r\nLignosulphonate/Drispac mud from 1025 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eA thin Eocene sand section was penetrated\r\nat 1460 m at Top Hordaland Group. A 2.7% mud gas peak (methane) was recorded in\r\nthis sand. At 1820 m Late Cretaceous sediments of the Lange Formation\r\n(Cenomanian age) was encountered. Below this section, at 1876 m, an undefined\r\nsection consisting of dolomite and thin sandstone beds was encountered. At this\r\npoint a 19.8 % mud gas peak was recorded. Metamorphic basement was encountered\r\nat 1912 m. Paleozoic sands were absent. No oil shows were recorded in the well.\r\nOrganic geochemical analyses of cuttings indicated traces of migrated\r\nhydrocarbons in the Cretaceous section from 1800 m to 1870 m. Only very poor\r\ngas prone source sections were identified in the well, which was found immature\r\nfor any petroleum generation all through. Two cores were cut in the metamorphic\r\nbasement. No fluid sample was taken. No sidewall cores were taken.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 3\r\nAugust 1983 as a dry hole.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was performed.\u003c/p\u003e\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"19","properties":{"OBJECTID":19,"wlbNpdidWellbore":20,"wlbName":"31/3-1","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThe wildcat 31/3-1 was drilled ca 17 km\r\nNNE of well 13/6-1 in the Troll East area. The two wells were drilled at the\r\nsame time and together they established the existence of a Troll East gas\r\nfield. The objective of 31/3-1 was to test possible gas and oil accumulations\r\nin sandstones of Late to Middle Jurassic age. Secondary objective was to test\r\npossible hydrocarbon accumulations in Middle to Early Jurassic and Late\r\nTriassic. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 31/3-1 was spudded with the\r\nsemi-submersible installation Deepsea Bergen on 17 July 1983 and drilled to TD\r\nat 2374 m in the Triassic Hegre Group. No significant problems occurred during\r\ndrilling except some technical problems when running the BOP for the 26"\r\nsection. The well was drilled with spud mud down to 865 m, with KCl/polymer\r\nfrom 865 m to 1300 m, with gel/lignosulphonate from 1300 m to 1833 m, and with\r\nlignite/lignosulphonate from 1833 m to TD. \u003c/p\u003e\r\n\r\n\u003cp\u003eTop reservoir (Sognefjord Formation) was\r\nencountered at 1351.5 m. The Sognefjord, Heather, and Fensfjord Formations were\r\nfound to hold a gas column of ca 220 m gas down to an approximate 4 m oil\r\ncolumn. The OWC was at ca 1576m.Geochemical analyses of the reservoir gas\r\nshow clear signs of biodegradation. Neither the Early Jurassic nor the Late\r\nTriassic contained hydrocarbons. \u003c/p\u003e\r\n\r\n\u003cp\u003eTwelve cores were cut continuously from\r\n1351 m to 1610 m in the Late and Middle Jurassic reservoir sequences. FMT fluid\r\nsamples were taken at 1374.2 m, 1570 m, 1574.2 m, and 1579.2 m.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 13\r\nOctober 1983 as a gas appraisal well.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eTwo DST's were performed, and gas was\r\nproduced from both. DST 1 was performed from the interval 1519 m to 1529 m and\r\nproduced 842400 Sm3 gas /day on a 22 mm choke. The gas had a gravity of 0.635\r\n(air = 1). DST2 was performed from the interval 1373 m to 1383 m and produced\r\n733500 Sm3 gas /day on a 19 mm choke. The gas had a gravit","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"20","properties":{"OBJECTID":20,"wlbNpdidWellbore":21,"wlbName":"7119/7-1","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eExploration well 7119/7-1 is located in\r\nthe Tromsø Basin, ca 30 km west of the Snøhvit Field area. The primary well\r\nobjective was to test a sandstone and/or limestone reservoir of Late Cretaceous\r\nage. The secondary objective of the well was to test a westward thinning wedge\r\ninterpreted as a sandstone reservoir of Late Cretaceous age. A further\r\nobjective of the well was to penetrate the Cenomanian unconformity with\r\npossible associated basal sandstones. Planned TD was 4100 m or 100 m below the\r\nCenomanian unconformity.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 7119/7-1 was spudded with the\r\nsemi-submersible installation Treasure Seeker on 12 July 1983 and was drilled\r\nto a total depth of 3167 m in salt. No major problems occurred during drilling.\r\nThe well was drilled with seawater and bentonite down to 622 m, and with\r\nKCl/polymer mud from 622 m to 2518 m. From 2518 m to TD the mud was converted\r\nto a dispersed gel system allowing natural depletion of the KCL. \u003c/p\u003e\r\n\r\n\u003cp\u003eNo rocks with reservoir qualities were\r\npenetrated by this well. The prognosed Campanian sandstones/limestones were\r\ndeveloped as claystones, sometimes silty with occasional limestone stringers.\r\nInsignificant traces of sand were noted in that interval. Top Campanian was\r\nfound between 1375 m and 1377 m based on biostratigraphy. The base Late\r\nCretaceous wedge interpreted as sandstone was found poorly developed as\r\nsiltstones and silty claystones without reservoir characteristics. The base\r\nLate Cretaceous was encountered between 2796.5 m and 2810.5 m based on\r\nbiostratigraphy. The Cenomanian unconformity was penetrated at 2529 m without\r\nany associated sandstones. The well encountered evaporites of possible Permian\r\nage at 3094.5 m. No shows were recorded in the well. No conventional cores were\r\ncut and no fluid samples taken\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 11\r\nSeptember 1983 as a dry hole.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was performed\u003c/p\u003e\r\n\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"21","properties":{"OBJECTID":21,"wlbNpdidWellbore":22,"wlbName":"31/6-1","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThe primary objectives of the wildcat\r\n31/6-1 was to test Late and Middle Jurassic sandstones on the main culmination\r\nof the Troll east structure in the western part of block 31/6. Secondary\r\nobjectives were Middle to Early Jurassic and Triassic sandstones and a possible\r\nsandstone reservoir of pre-Triassic age within a set of tilted fault blocks\r\nburied by Triassic strata. The Troll east structure is a large tilted fault\r\nblock containing Jurassic and older strata. The closure\u003c/p\u003e\r\n\r\n\u003cp\u003eat Sognefjord Formation level is\r\ndelineated by a flatspot covering most of the 31/6 block. The flatspot was\r\nexpected to be a gas/fluid contact evident on the seismic and penetrated by\r\nnine wells in the Troll West area to the NNW in block 31/2. Planned TD of the well\r\nwas 3800 m into rocks of pre-Triassic (? Devonian age).\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 31/6-1 was spudded with the\r\nsemi-submersible installation Nortrym on 15 July 1983 and drilled to TD at 4070\r\nm in pre-Devonian basement rock. Problems with getting logging tools past the\r\n30" casing shoe occurred due to gumbo problems. Further drilling went\r\nforth without major problems. The well was drilled with spud mud down to 425 m,\r\nwith seawater / prehydrated gel and hi-vis pills from 425 m to 749 m, and with\r\nKCl/polymer/PHPA mud from 749 m to TD \u003c/p\u003e\r\n\r\n\u003cp\u003eThe total net sand in the Viking Group\r\n(1352-1805 m) found to be 424.25 m giving a net/gross ratio of 0.94 m with an\r\naverage porosity of 27.5%. The Sognefjord Formation (1352-1488 m), the Heather\r\nFormation Unit B, (1488-1517.5 m) and the upper part of the Fensfjord Formation\r\nwere found gas bearing from 1352 to 1571 m where the gas/oil contact was found.\r\nBelow this a thin (3 m) oil zone was present with an oil/water contact at\r\napproximately 1574 m. The hydrocarbon-bearing reservoir consisted of very fine\r\nto fine grained sandstones, occasionally medium to coarse. They were generally\r\nfriable to loose with a few tight calcite cemented stringers. The","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"22","properties":{"OBJECTID":22,"wlbNpdidWellbore":23,"wlbName":"34/10-18","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 34/10-18 is located in the Tampen\r\nSpur area, south of the Vigdis Field and west-north-west of the Gullfaks Field.\r\nThe primary objective was the Brent Group sandstones of Middle Jurassic age. Secondary\r\nobjectives were Early Jurassic Cook and Statfjord Formation sandstones.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 34/10-18 was spudded with\r\nthe semi-submersible installation Ross Isle on 17 July 1983. A 12 1/4"\r\npilot hole was drilled from the 30" casing shoe to 765 m to check for shallow\r\ngas. No shallow gas was seen, but lost circulation occurred in shallow sand lenses\r\nwhen the pilot was underreamed to 26". A 17 1/2" hole was drilled and\r\nlogged to 2024 m. Two joints of 13 3/8" casing were dropped in the hole.\r\nThe hole was cemented back to 1882 m and sidetracked from 1900 m and drilled\r\nwithout significant problems to TD at 3025 m in the Early Jurassic Statfjord\r\nFormation. The well was drilled with spud mud down to 765 m and with\r\ngel/Lignosulphonate mud from 765 m to TD. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo live oil was seen in the well, but a\r\n3.5 m unproductive oil-zone was encountered in a, sandy/marly and cemented\r\nlimestone at the base of a very thin Cromer Knoll sequence (Mime Formation).\r\nThe average porosity was 24.3% and the average water saturation was 53.4%, but\r\ndue to tight formation the RFT was not able to obtain any pressure points in\r\nthis zone. The permeability range was 0.1 to 1 mD. Only residual hydrocarbons\r\nwere encountered in the Brent sandstones.\u003c/span\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003cspan\r\nlang=EN-US\u003eHere, t\u003c/span\u003e\u003cspan lang=EN-GB\u003ehe logs indicated an average water saturation\r\nof 95% and an average porosity of 24.2% in the net sand.\u003c/span\u003e\u003cspan\r\nlang=EN-GB\u003e \u003c/span\u003e\u003cspan lang=EN-GB\u003eThe RFT plot suggested a water gradient of\r\n1.00 g/","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"23","properties":{"OBJECTID":23,"wlbNpdidWellbore":24,"wlbName":"6609/10-1","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 6609/10-1 is located on the\r\nTrøndelag Platform outside Mid Norway. The objective was to test the entire\r\nstratigraphic column between the seabed and into the Late Triassic. The primary\r\ntarget of the well was Jurassic sandstones on the Nordland Ridge, secondary to\r\ntest possible sand development in the Paleocene. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 6609/10-1 was spudded with\r\nthe semi-submersible installation Treasure Saga on 2 August 1983 and drilled to\r\nTD at 2167 m in the Late Triassic Red Beds. The well was drilled with spud mud\r\ndown to 413 m, adding some lignosulphonate (Unical) from 413 m to 1265 m, and\r\nwith a full lignosulphonate mud from 1265 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eApart from the glaciomarine sands and\r\nsilts of Pleistocene age at the top, the well proved mainly clay and clay stone\r\ndown to the Lower Jurassic Sandstone. In the Tertiary two unconformities were\r\nseen; a Late Miocene unconformity at 1312 m and a major unconformity at 1367 m,\r\nranging in age from Early Eocene to Middle Miocene. The Tertiary unconformably\r\noverlies the Late Cretaceous, which in the well is of Campanian-Early\r\nMaastrichtian age. This section rests unconformably on Middle Jurassic (Late\r\nToarcian-Early Bajocian) claystones at 1605 m. Beneath a Middle/Early Jurassic\r\nunconformity at 1642 m the well penetrated Tilje Formation Sandstone (143 m\r\nthick), the Åre Formation 1733 - 1993 m) and the Triassic Grey and Red Beds.\r\nBoth the Tilje and Åre Formation sandstones had significant shale content. The\r\ndrilling proved the pressure to be hydrostatic throughout the entire well. The\r\nformation pressure is approximately 170 bar at 1700 m. The sand intervals\r\napparently belong to the same pressure regime. All sands proved water bearing.\r\nNo shows were recorded in any section of the well. \u003c/p\u003e\r\n\r\n\u003cp\u003eAs the Late Jurassic was not present in\r\nthe well location the only potential source rock found in the well was the\r\nEarly Jurassic - Late Triassic "Coal Unit" (År","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"24","properties":{"OBJECTID":24,"wlbNpdidWellbore":25,"wlbName":"2/5-7","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 2/5-7 is located ca 9 km\r\nNorth of the Tor Field in the southern Norwegian North Sea. The primary\r\nobjective was to test Late Jurassic and Middle Jurassic/Triassic sandstones on\r\ntop of a gentle salt-induced dome structure. Secondary objectives were Late\r\nCretaceous chalk and Paleocene sandstones. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell was spudded with the jack-up\r\ninstallation Neddrill Trigon on 11 August 1983 and drilled to TD at 4531 m in\r\nthe Triassic Skagerrak Formation. During drilling of the 17 1/2" hole\r\nseveral tight spots and problems with cavings were experienced. While tripping\r\nout of the hole at 3956 m, the drill string parted and 193 m of the bottom hole\r\nassembly was left in the hole. The fish was recovered after some problems due\r\nto tight hole conditions. When pressure testing the 9 5/8" casing the\r\nfloat collar sheared out causing the casing to jump. After re-landing, the\r\ncasing was found to have dropped a couple of inches. Repair of the casing took\r\n35 days extra rig time. A drilling break occurred at 4161 m where a 1.5 m thick\r\nmarl was encountered. Maximum gas reading at bottoms-up was 30 %, and slight\r\noil shows were observed in the mud. A kick was taken at 4519 m with an influx\r\nof 2.5 m3 water. The well was drilled with seawater and gel down to 862 m, with\r\nKCl/polymer mud from 862 m to 2254 m, with lignosulphonate mud from 2254 m to\r\n3529 m, and with gel/lignosulphonate mud from 3529 m to TD. \u003c/p\u003e\r\n\r\n\u003cp\u003eOnly traces of sandstone were encountered\r\nin the Late Paleocene, and there were no indications of hydrocarbons. Porous\r\nchalk was encountered in the Ekofisk Formation at 3204 m and in the Tor\r\nFormation at 3289 m. Both formations tested oil, but the oil flow in the\r\nEkofisk test was interpreted to originate from the Tor Formation (see below).\r\nThe matrix permeability in these zones is low, but the results from the\r\nproduction tests indicated that fracture permeability is significant. No\r\nhydrocarbons were found in the L","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"25","properties":{"OBJECTID":25,"wlbNpdidWellbore":26,"wlbName":"6610/7-2","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 6610/7-2 is located on the\r\nTrøndelag Platform outside Mid Norway. The primary objective of the well was to\r\ntest the hydrocarbon potential of Early Jurassic and Late Triassic sandstones.\r\nSecondary objectives were to gather information about the stratigraphy and\r\nhydrocarbon potential down to approximately 4200 m. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 6610/7-2 was spudded with\r\nthe semi-submersible installation West Vanguard on 28 August 1983 and drilled\r\nto TD at 4215 m in the Triassic Grey Beds. Drilling operations were problematic\r\nand took 119 days more than programmed. Excessive reaming of tight spots had to\r\nbe done during drilling of the 22" hole section. In all the four first\r\nhole sections a pilot hole was drilled before underreaming. Nineteen kg junk\r\nwas recovered from the hole after drilling out of the 13 3/8" casing shoe.\r\nSeveral problems with stuck pipe occurred below 3000 m. At 3526 m the pipe was\r\nstuck and was backed off at 3315 m. A cement plug was set from 3292 to 3148 m\r\nand the hole was sidetracked from 3212 m. Severe problems with tight hole, was\r\nexperienced down to 3361 m. The well was drilled with seawater and spud mud\r\ndown to 701 m, with gypsum/lignosulphonate mud from 701 m to 2160 m. Due to\r\nexpected salt beds below 2500 m the well was drilled with oil based mud from\r\n2160 m to TD. The oil base used was a Norol product, "hvitolje", a\r\nlow-aromatic mineral oil C13 - C20 distillate.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well encountered several sandstone\r\nbodies, the first interpreted as the Egga Informal Unit in Paleocene. Earliest\r\nCretaceous - Late Jurassic were not present in the well. At 1487 m the Early\r\nJurassic Båt Group was encountered with massive and porous sandstone sequence.\r\nThe Triassic interval 3473 - 4218 m also had some clean sandstone, especially\r\nin the upper part. Electrical logs and RFT pressure tests, however, proved all\r\npotential reservoirs to be water bearing. Organic geochemical analyses showed","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"26","properties":{"OBJECTID":26,"wlbNpdidWellbore":27,"wlbName":"31/5-1","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\u003cp\u003eWell 31/5-1 was drilled as an appraisal well\r\nat the southern part of the Troll West Field. The purpose of the well was to\r\ntest the reservoir qualities, the oil/gas columns, and the hydrocarbon/water\r\ncontact in the area.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eAppraisal well 31/5-1 was spudded with\r\nthe semi-submersible installation Treasure Saga on 5 September 1983. The well\r\nwas drilled with seawater and hi-vis pills all through. After drilling to 860 m\r\nand setting the 20" casing, the BOP was run on riser. When the BOP was 12\r\nm above the well head the drill pipe elevator broke, and the BOP dropped down\r\nand damaged the well head. The BOP and some riser joints were recovered before\r\nthe rig was towed to Bergen where the BOP was changed.\u003c/p\u003e\r\n\r\n\u003cp\u003eNo cores were cut and no wire line fluid\r\nsamples were taken.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was abandoned on 30 September\r\n1983 as a junk well. After repairs Treasure Saga returned to the location on 5\r\nOctober 1983 to spud replacement well 31/5-2.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was performed.\u003c/p\u003e\r\n\r\n\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"27","properties":{"OBJECTID":27,"wlbNpdidWellbore":28,"wlbName":"7/8-3","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 7/8-3 is located in the North Sea, north of the Mime field on the margin of the Cod Terrace. The primary objective\r\nof 7/8-3 was to explore the hydrocarbon potential of the Late Jurassic\r\nsandstones. Secondary objectives were to explore the Cretaceous Chalk and the\r\nTriassic sandstones. Planned TD was at 4275 m in Permian salt.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 7/8-3 was spudded with the\r\nsemi-submersible installation Borgny Dolphin on 12 September 1983 and drilled\r\nto TD at 4320 m in the Late Permian Zechstein Group. While running 13 3/8"\r\ncasing this got stuck and had to be pulled out of the hole. The hole was\r\ncleaned and new casing was set without further complications. Otherwise no\r\nsignificant problems were encountered during drilling. The well was drilled\r\nwith spud mud down to 199 m and with KCl polymer mud from 199 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe Cretaceous Chalk was encountered at a\r\ndepth of 3024 m, the Late Jurassic Ula Formation at 3724 m, and the Triassic at\r\n3767 m. The Ula Formation sandstones were hydrocarbon bearing within a 43.5 m\r\ngross sand interval. No oil/water contact was encountered. Oil shows were\r\nrecorded in shales and porous sections from 3699 m to 3751 m.\u003c/p\u003e\r\n\r\n\u003cp\u003eFour cores were cut in the interval 3731\r\nm to 3773 m, three in the Upper Jurassic Ula Formation and one into Upper\r\nTriassic sandstones. A RFT fluid sample from the Triassic section at 4049.5 m\r\nrecovered only mud filtrate.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 12\r\nDecember 1983 as an oil discovery.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eTwo DST's were performed in the Ula\r\nFormation sandstones: DST 1 from interval 3762 m to 3767 m, and DST 2 from\r\ninterval 3734.5 m to 3740.5 m. The first produced oil at a slightly declining\r\nrate during the final 5-hours flow period, the average rate being 207 Sm3/day\r\nthrough a 2" choke. The GOR was 32 Sm3/Sm3, API oil gravity was 29 deg,\r\nand gas gravity was 0.88 (air = 1). The second DST produced 70 Sm3 oil/day\r\nth","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"28","properties":{"OBJECTID":28,"wlbNpdidWellbore":29,"wlbName":"6407/1-3","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 6407/1-3 was drilled in the\r\nHaltenbanken area off shore Mid Norway. It is situated on a separate but\r\nrelated structure to 6407/1-2, which found gas-condensate in the Middle\r\nJurassic Garn Formation. The primary target of well 6407/1-3 was Middle\r\nJurassic sandstones. Secondary target was Early Jurassic sandstones. Other\r\nzones of interest were the Late and Early Cretaceous and the coal unit in the\r\nEarly Jurassic. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe well is Type Well for the Brygge\r\nFormation and Reference Well for the Hordaland Group, it is Type Well for the\r\nGarn Formation, and it is Reference Well for the Ile and Not Formations.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 6407/1-3 was spudded with\r\nthe semi-submersible installation Dyvi Delta on 17 September 1983 and drilled\r\nto TD at 4469 m in Late Triassic sediments of the Åre Formation. Hole problems\r\noccurred when running back in the hole after a period of bad weather. The hole\r\nhad collapsed and had to be reamed back to bottom at 3136 M. A drilling break\r\noccurred at 3746 to 3748 m. All in all, there was a total of 16 days downtime\r\ncaused by bad weather. Still, the well was drilled 22 days faster than\r\nprognosed. This was mainly due to fast penetration in the 17 1/2" and\r\n6" hole, an efficient coring operation and favourable weather conditions\r\ncompared to well 6407/1-2. The well was drilled with seawater/gel down to 948\r\nm, with lignosulphonate/gypsum from 948 m to 3608 m, and with bentonite gel\r\nfrom 3608 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eHydrocarbon bearing Middle Jurassic\r\nsandstones (Garn Formation) were encountered at 3600 m. A gas cap extended to\r\n3687.5 m followed by an oil zone down to 3709 m. At this point the sand grades\r\nrapidly into the underlying silt and clay of the Not Formation at 3709.5 m.\r\nThis makes it difficult to conclude on an OWC for the discovery. The Nise\r\nFormation from 2448 m to 2601 m had good gas shows whilst drilling and oil\r\ncontamination of drilling mud. Mud log data suggested a possibl","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"29","properties":{"OBJECTID":29,"wlbNpdidWellbore":30,"wlbName":"7/11-8","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 7/11-8 is located on the Cod\r\nTerrace of the North Sea, between the Mime Field to the South and the 7/8-3\r\nDiscovery to the North. The primary objective was to test Late Jurassic\r\nsandstones of the Ula Formation. Secondary objective of the well was to test\r\ncontinental sandstone reservoirs of Triassic age as seen in some nearby wells.\r\nRocks of early and middle Jurassic age were thought to be absent at this\r\nlocation. The well was planned to be drilled to 4550 + 100 m, approximately 730\r\nm into the Triassic to penetrate a strong intra Triassic reflector.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 7/11-8 was spudded with the\r\nsemi-submersible installation Treasure Scout on 22 September 1983 and drilled\r\nto TD at 4750 m, almost one km into Triassic sediments. Gumbo problems and\r\nproblems with the seal assembly were experienced when running the 13 3/8"\r\ncasing. The well was drilled with seawater and pre-hydrated bentonite down to\r\n620 m, with KCl polymer mud from 620 m to 3673 m, and with a bentonite/lignosulphonate/barite/lignite\r\nmud system from 3673 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well encountered water bearing\r\nTriassic sandstones directly underlying lower Cretaceous shales. The Ula\r\nFormation was thus missing. No shows or other hydrocarbon indications were seen\r\nin the well. The intra Triassic marker was found at 4605 m in a shaly sequence.\u003c/p\u003e\r\n\r\n\u003cp\u003eOne core was cut in the Triassic\r\nsandstones from 3725 to 3743.95 m. The entire core consisted of greyish red to\r\nmoderate brown sandstones, with occasional bands of greenish black to greenish\r\ngrey sandstones. The RFT tool was run to obtain pressure points in the Triassic\r\nsands. The pressure data indicated a water gradient of 1.09 g/cm3 and no fluid\r\nsample was taken\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 12\r\nDecember 1983 as a dry well.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was performed\u003c/p\u003e\r\n\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"30","properties":{"OBJECTID":30,"wlbNpdidWellbore":31,"wlbName":"29/9-1","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 29/9-1 is located on the Hild\r\nstructure ca 1.5 km west of the UK border on the eastern margin of the East\r\nShetland Basin in the North Sea. The well was drilled to appraise the 30/7-2\r\ndiscovery. The main objectives were to test the hydrocarbon prospectivity and\r\nreservoir parameters of the Middle and Early Jurassic sequence. The well was\r\nplanned to be drilled 50 m into the Statfjord Formation at a total depth of\r\n4640 +/- 200 m.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 29/9-1 was spudded with\r\nthe semi-submersible installation Treasure Seeker on 23 September 1983 and\r\ndrilled to TD at 4703 m in the Early Jurassic Statfjord Formation. During\r\ndrilling of the 17 1/2" hole, tight hole problems were experienced. The 9\r\n5/8" casing had to be run twice due to problems with the casing hanger\r\nseal. Due to high temperature and lack of circulation the mud in the 7"\r\nliner gelled up and had to be replaced several times. This caused difficulties\r\noperating the testing tool. The well was drilled with seawater and gel slugs\r\ndown to 1057 m and with KCl/polymer mud from 1057 m to TD. Mud retort test\r\nshowed 4-5% oil in the mud from top of the 12 1/4" section at 2752 m,\r\ndeclining to traces at 3732 m.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well encountered oil in the Frigg\r\nFormation in the interval 1782 to 1787 m (OWC), and gas in the middle Jurassic\r\nBrent Group from 4386.5 m to 4421 m (gas down to top Dunlin Group; no\r\nhydrocarbon contact was encountered).\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe Frigg Formation (1782-1981 m) consisted\r\nof predominantly of fine to coarse grained porous sandstones. The uppermost 2.5\r\nm was tight and calcareous cemented. Net pay was thus 2.5 m with 31% average\r\nporosity and 40% average water saturation, based on logs. No ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"31","properties":{"OBJECTID":31,"wlbNpdidWellbore":32,"wlbName":"31/5-2","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 31/5-2 is a replacement well for well\r\n3/5-1 in the southern part of the Troll West Field. Well 31/5-1 was terminated\r\nat 860 m and junked due to an incident where the BOP and riser was lost. Due to\r\nthis, the rig left the location and went to Bergen for repairs. It returned to\r\nthe location five days later for drilling 31/5-2. The purpose of the well was to\r\ntest the reservoir qualities, the oil/gas columns, and the hydrocarbon/water\r\ncontact in the area. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eAppraisal well 31/5-2 was spudded with\r\nthe semi-submersible installation Treasure Saga on 5 October 1983 and was\r\ndrilled to TD at 2500 m in the Late Triassic Hegre Group. A total of 5 days\r\nwere lost on setting the 18 3/4" x 9 5/8" seal-assembly, otherwise no\r\nsignificant technical problems occurred in the operations. The well was drilled\r\nwith seawater and hi-vis pills down to 860 m and with KCl/polymer mud from 860\r\nm to TD. \u003c/p\u003e\r\n\r\n\u003cp\u003eWell 31/5-2 penetrated top reservoir at\r\n1521 m. The interval 1521 - 1569 m was gas bearing with 30% porosity and 15%\r\nwater saturation. The interval from 1569 - 1582 m was oil bearing with 27%\r\nporosity and 30% water saturations. These intervals were the only hydrocarbon\r\nbearing intervals in the well. Between 1569 and 1582 m there were good shows in\r\nthe cores. They showed brown oil stain, golden-yellow fluorescence and instant\r\ncloudy, milky, white cut. There was strong hydrocarbon odour.\u003c/p\u003e\r\n\r\n\u003cp\u003eA total of six cores were taken in the\r\ninterval 1505.0 -1599.9 m, covering the basal 16 m of the Draupne Formation and\r\nthe upper 78 m of the Sognefjord Formation. The core recovery was 81%. FMT\r\nsegregated fluid samples were taken at 1563 m (gas), 1575 m (oil at 135 bar),\r\nand 1581 (oil at 90 bar).\u003c/p\u003e\r\n\r\n\u003cp\u003eAfter surveying, logging and sidewall\r\ncoring, the well was plugged back to 1902 m and suspended on 11 November 1984.\r\nThe well was to be re-entered at a later stage for testing.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"32","properties":{"OBJECTID":32,"wlbNpdidWellbore":33,"wlbName":"34/10-19","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 34/10-19 was drilled to investigate\r\nthe southern section of the Gullfaks Phase II area. The primary objective was to\r\npenetrate the Cook sandstone above the oil water contact at 2118 m seen in well\r\n34/10-9, and to improve the understanding of the reserve distribution in this\r\npart of the Gullfaks field. Secondary objective was the Statfjord sandstone. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 34/10-19 was spudded with\r\nthe semi-submersible installation Ross Isle on 5 October 1983 and drilled to TD\r\nat 2218 m in the Triassic Hegre Formation. Shallow gas was encountered in a\r\nsand at 332 to 338 m. A 16" liner was required to stop gas flow between\r\n20" and 30" casings. Several drilling breaks occurred in the 12\r\n1/4" hole and lost circulation occurred in the 8 1/2" hole. The well\r\nwas drilled with gel/seawater down to 8978 m, with gel/seawater/hi-vis pills\r\nfrom 978 m to 1494 m, and with gel/lignosulphonate/lignite mud from 1494 m to\r\nTD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe upper sandstone part of the Cook\r\nformation (unit C3 and C2) was missing missing due to faulting and erosion. The\r\nlower Cook C1 unit was penetrated at 1779 m. This unit consists of dominantly\r\nclaystones and it was water bearing. The sandstones of the Statfjord Formation\r\nwere water bearing. Trace shows were recorded in the Hordaland Group on\r\nclaystones from 960 m to 120 m and on claystone and on limestone from 1340 m to\r\n1470 m. Trace to fair shows on siltstone, claystone and minor sandstones were\r\nrecorded intermittently below 1470 m and down to 1861 m. No trace of\r\nhydrocarbons was seen below this depth.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThree cores were cut; one in the interval\r\nfrom 1763 in the Cromer Knoll Group to 1781.3 m in the Cook Formation, and two in","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"33","properties":{"OBJECTID":33,"wlbNpdidWellbore":34,"wlbName":"31/6-2","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eAppraisal well 31/6-2 was drilled on a\r\nlocation on the south-east periphery on the Troll East gas province. The main\r\nobjective was to test the gas and oil accumulations in sandstones of Late to\r\nMiddle Jurassic age. The planned TD was about 200 m into rocks of Triassic age\r\nto an estimated total depth of 2400 m RKB.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well is Reference well for the\r\nHardråde Formation and for the undifferentiated Shetland Group in the Troll\r\narea.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 31/6-2 was spudded with the\r\nsemi-submersible installation Deepsea Bergen on 18 October 1983 and drilled to\r\nTD at 2020 m in the Early Jurassic Drake Formation. Because of problems with a\r\nleak in 20" casing and lost circulation problems in a major fault, both 13\r\n3/8" and 9 5/8" casing had to be set high. The well was drilled with\r\nsea water and hi-vis pills down to 412 m, with AQUAGEL/seawater spud mud from\r\n412 m to 801 m, with KCl polymer mud from 801 m to TD. At 984 m Lost\r\nCirculation Material -pills were added to cure lost circulation problems.\u003c/p\u003e\r\n\r\n\u003cp\u003eNo reservoir sections were developed\r\nabove the Jurassic. The well encountered 113 m of Draupne shale with top at\r\n1322 m, overlying a 25 m thick Heather Formation sequence. The Sognefjord\r\nFormation sandstone reservoir was encountered at 1460 m with a gas column of\r\napproximately 110 m. No oil leg could be detected from electric logs or FMT's.\r\nOil shows were recorded on sidewall core sandstone in the interval from 1831 m\r\nto 1988 m in the Middle to Early Jurassic. Nine cores were cut from 1435 m to\r\n1619 m in the Heather and Sognefjord Formations. FMT sampling in the Sognefjord\r\nFormation recovered small amounts of gas from 1475 m and 1572 m. A sample from\r\n1577 m gave mud filtrate.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was suspended on 11 December\r\n1983 as a gas appraisal.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was performed.\u003c/p\u003e\r\n\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"34","properties":{"OBJECTID":34,"wlbNpdidWellbore":35,"wlbName":"31/6-3","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThe primary objective of the wildcat\r\n31/6-3 was to assess possible hydrocarbon accumulations in the sands and\r\nsandstones of the Late Jurassic Sognefjord Formation. The target was prospect\r\nC, a structural trap in the southeastern corner of block 31/6 extending into\r\nthe adjacent blocks 31/9, 32/4 and 32/7. The well was located on the apex of\r\nprospect C. The secondary objective of the well was to obtain Sedimentological\r\ndata for the Sognefjord Formation sandstones in the well location. The well was\r\nplanned to reach total depth at ca 2200 m, approximately 100 m into the\r\nTriassic.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was spudded with the\r\nsemi-submersible installation Nortrym on 1 November 1983. Repositioning of the\r\nrig had to be done due to anchoring problems. At 1950 m the drill string was\r\nhung off. Problems when attempting to retrieve the drill string resulted in\r\npulling of BOP. When running in hole after 7 days, 10 m of fill was found. No\r\nother major problems occurred during drilling and the well reached planned TD\r\nat 2250 m in the Triassic Hegre Group. The well was drilled with seawater and\r\nhi-vis pills down to 618 m and with KCl/Polymer mud from 618 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well encountered water-bearing\r\nsandstones in the Late/Middle Jurassic Sognefjord Formation as well as in the\r\nlower lying sandstones. No oil shows were noted on cores, sidewall cores or\r\ncuttings in any section of the well. Gas readings were low or nil throughout\r\nexcept for a 2.6% methane reading in a shallow sand unit at 414 m. The Sognefjord\r\nFormation sandstones (1511-1647 m) are very fine to fine, occasionally medium\r\ngrained, micaceous, occasionally carbonaceous and slightly argillaceous. In\r\nplaces the sandstones grade into siltstones. They are well to moderately sorted\r\nand have fair visible porosity. The underlying Sognefjord, Fensfjord, and\r\nKrossfjord Formations (1647-1931.5m) are dominated by fine to medium, locally\r\nvery fine or coarse grained sandstones which are o","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"35","properties":{"OBJECTID":35,"wlbNpdidWellbore":36,"wlbName":"15/9-18","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 15/9-18 is located between the\r\nSleipner Øst and Sleipner Vest Fields in the South Viking Graben in the North\r\nSea.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eIt was designed primarily to test\r\nhydrocarbon accumulations in the Middle Jurassic Hugin Formation. Secondary objectives\r\nwere Paleocene sandstones in the Heimdal and Sleipner Formations, and\r\nsandstones of Triassic age. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 15/9-18 was spudded with the\r\nsemi-submersible installation Deepsea Bergen on 16 December 1983 and drilled to\r\nTD at 3622 m in the Triassic Smith Bank Fm. No major problems occurred while\r\ndrilling this well, but some tight hole problems were experienced in the 12\r\n1/4" hole section. The well was drilled with seawater gel down to 520 m\r\nand with gypsum/lignosulphonate mud from 520 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eTertiary sands were penetrated at 866 m\r\n(Utsira Formation), 1254 m, and at 2071 m ("Frigg Fm Equivalent"). The\r\nDraupne Formation was encountered 105 m thick at 3108 m. The Hugin Formation\r\nwas encountered at 3237 m. It was found hydrocarbon bearing in a 7.5 m interval\r\nfrom 3237.5 m and down to a coal layer at 3245.0 m but the hydrocarbons were\r\nimmovable. The well did not encounter other hydrocarbon bearing intervals. Shows\r\nwere however recorded further down in the Hugin Formation in the interval 3275\r\nm to 3325 m. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eFour cores were cut, two in the Paleocene\r\nand two in the Middle Jurassic sequence. Segregated FMT fluid samples were\r\ntaken in the hydrocarbon bearing interval in the Hugin Formation at 3238.3 m,\r\n3239 m, and 3240 m. All samples were reported to recover mud filtrate only, but\r\nthe samples from 3240 m were analysed to contain 0.2 g petroleum hydrocarbons.\u003c","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"36","properties":{"OBJECTID":36,"wlbNpdidWellbore":37,"wlbName":"34/4-5","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 34/4-5 was drilled on the\r\nMort Horst in the Northeastern part of the block. The purpose of the well was\r\nto test the Zeta structure for hydrocarbons and to test the stratigraphy below\r\nthe Base Cretaceous Unconformity. The well encountered hydrocarbons in the Cook\r\nFormation and in the Statfjord Formation. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was spudded with the\r\nsemi-submersible installation Treasure Saga on November 13 1983 and drilled to\r\nTD at 3917 m in Early - Middle Triassic sediments of the Lunde Formation. The\r\nwell was drilled with seawater and bentonite down to 533 m, with\r\nbentonite/gypsum mud from 533 m to 1113 m, with gypsum/polymer mud from 1113 m\r\nto 2025 m, with gypsum/lignosulfonate (Unical) mud from 2025 m to 3200 m, and\r\nwith lignosulfonate from 3200 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eDue to severe boulder problems in the\r\n26" hole section, the well had to be re-spudded three times before the\r\n20" casing could be run and cemented. The 20" casing had to be worked\r\nand washed down to the planned depth. This action most likely buckled or partly\r\ncollapsed the 20" casing. It took approximately 5 days to drill/mill out\r\nthe bottom section of the 20" casing. Circulation was lost at 2026 m when\r\ndrilling the 17 1/2" hole. Due to the lost circulation, the 13 3/8"\r\ncasing had to be set at 2011 m. The 12 1/4" section had to be plugged back\r\nfrom 3106 m to 3005 m due to severe hole deviation problems. The maximum hole\r\nangle was 8.75°. Re-drilling this hole section and deepening it down to 3200 m\r\nthe hole angle varied between 3° and 4°. The 9 5/8" casing was set at 3195\r\nm. The 8 1/2" hole section was drilled down to 3424 m, where the first\r\ncore was cut. The core recovered shale, and it was decided to drill ahead. The\r\nhole was drilled down to 3470 m, where a new drill break occurred. While\r\ncirculating bottoms up for samples a kick was taken. A total of 43 bbls were\r\ngained before closing in the well","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"37","properties":{"OBJECTID":37,"wlbNpdidWellbore":38,"wlbName":"15/6-6","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 15/6-6 was drilled to appraise the north\r\neastern flank of Alpha structure on the 15/6-3 Sleipner Vest Discovery in the North Sea. The primary target was a gas bearing Jurassic sandstone known as the Hugin Formation.\r\nIt was drilled to provide needed structural control and to establish a\r\ngas/water contact. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eAppraisal well 15/6-6 was spudded with\r\nthe semi-submersible installation Glomar Biscay II on 1 April 1982 and drilled\r\nto TD at 3760 m in Late Triassic sediments of the Skagerrak Formation. The\r\n36" hole had to be reamed several times due to ledging. This also occurred\r\nin the top of the 26" section. Forty-six bbl's (7.3 m3) of fluid were lost\r\nto the formation during cementing of the 13 3/8" casing. The mud weight in\r\nthis section was 1.68 which is lower than the previous Sleipner wells. This and\r\nthe fluid loss can possibly be related to an unconsolidated sand (Skade\r\nFormation) interval from 1185 to 1199 m. Minor hole problems were encountered\r\nin the 12 1/4" section. The drill string was temporarily stuck at 1627 m\r\nafter making a connection. The well was drilled with seawater and gel.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well proved sands in the Utsira, Grid,\r\nHeimdal, and Sleipner Formations; all water bearing. The gas bearing Hugin\r\nFormation was encountered at 3563 m and had a gross thickness of 58 m. The\r\ngas/water contact was found at 3607 m, which gives a gross gas interval of 44\r\nm. No oil shows were reported from the target reservoir or other sections in\r\nthe well.\u003c/p\u003e\r\n\r\n\u003cp\u003eThree cores were taken in the Middle\r\nJurassic interval in the 8 1/2" section. Core 1 recovered 18.5 m sandstone\r\nfrom 3591 m to 3609.5 m. Core 2 recovered 16.0 m sandstone from 3609.5 m to\r\n3622 m. Core 3 recovered 18.9 m Sandstone, shale and coal from 3625.5 m to\r\n3644.5 m. No wire line fluid sample was taken. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 9 June 1982 as a gas appraisal well.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well w","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"38","properties":{"OBJECTID":38,"wlbNpdidWellbore":39,"wlbName":"30/6-6","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 30/6-6 was drilled on the 30/6 Alpha\r\nstructure (Oseberg fault block) in the North Sea, as the fifth well drilled on\r\nthis structure. The well was drilled down-dip of 30/6-3 and 30/6-4. The primary\r\nobjective of this well was to define the oil-water contact for the structure. This\r\nwould be achieved by penetrating the OWC or by extrapolation of fluid gradients\r\nfrom RFT and DST pressure measurements.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 30/6-6 was spudded with\r\nthe semi-submersible installation Deepsea Saga on 9 January 1982 and drilled to\r\nTD at 3225 m in the Early Jurassic Cook Formation. Drilling operations proceeded\r\nwithout specific problems down to ca 1300 m. At this depth problems related to excessive\r\ntorque and drag on short trips occurred. The mud weight was then reduced from\r\n1.4 to 1.29 after which drilling again proceeded without problems. The well was\r\ndrilled with spud mud down to 200 m, with Gel/seawater/spud mud from 200 m to\r\n1793 m, and with gel/lignosulphonate mud from 1793 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eTop Viking Group was penetrated at 2587 m\r\nand consisted of 113 m Draupne Formation shales on top of 120 m Heather\r\nFormation. The Brent Group was encountered at 2820 m. It was water bearing.\r\nCombined RFT-pressures from 30/6-6 and 30/6-4 gave an oil/water contact at 2720\r\n+/- 20 m, which was later confirmed by the build-up pressures from the DST and\r\nthe calculated water density under reservoir conditions. No indications of H2S\r\nwere seen in this well. No shows are reported from the well.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThree cores were taken in the Ness and\r\nEtive formations from 2921 m - 2964 m. RFT water samples were attempted at 2879\r\nm, 2955 m and 2956 m, but were only moderately successful due to poor recovery\r\nand ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"39","properties":{"OBJECTID":39,"wlbNpdidWellbore":40,"wlbName":"16/7-2","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThe 16/7-2 well was drilled on the\r\nwestern flank of the Utsira High in the North Sea. The primary objective was to\r\ntest the presence of a stratigraphic trap in Paleocene sandstones. Secondary\r\nobjectives were to test the Mesozoic structure for possible Triassic sands, and\r\nalso to test the Zechstein carbonate and Rotliegendes sandstone plays. The well\r\nwas the first to be drilled in connection with the 6th. License Round awards. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 16/7-2 was spudded with the\r\nsemi-submersible installation Glomar Biscay II on 11 January 1982 and drilled\r\nto TD at 3146 m in Early Permian, Rotliegendes Group sediments. Drilling of the\r\n36" and 26" holes went forth without any specific problems. While\r\ncementing the 20" casing, the cement slurry was overdisplaced. A remedial\r\nsqueeze job was necessary. Problems also occurred when logging the 12 1/4"\r\nsection due to tight hole. In the 8 1/2" inch section problems with the\r\nBOP choke valve/controls led to close to 9 days lost time, a major reason for\r\nthe 38% non-productive time in this well. The well was drilled with seawater\r\ngel down to 171 m, and with lignite/lignosulphonate mud from 171 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eTop Lista Formation was encountered at\r\n2268 m and contained 9.5 m net of gas from 2292 m in thin sandstone intervals,\r\ninterbedded with shales. The average porosity is 22% and average water\r\nsaturation is 47% in the net sand. The Heimdal Formation sandstones were\r\nmassive, of very good reservoir quality, and contained 13.5 m of net gas sand\r\nin a gross gas sand interval of 13.5 m down to the gas/water contact at 2352 m.\r\nThe average porosity is 26% and average water saturation is 34%. The well was\r\ndrilled on the crest of a structurally limited trap and the gas accumulation is\r\nnot connected to the 15/9 Paleocene Gamma discovery. In the Jurassic, 19 m of\r\nwater wet Hugin Formation sand was encountered. The Zechstein dolomites and\r\nRotliegendes sandstones were also wat","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"40","properties":{"OBJECTID":40,"wlbNpdidWellbore":41,"wlbName":"34/4-4","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u00A0\u00A0\u00A0\u00A0\u00A0\u00A0\u00A0\u00A0\u00A0\u00A0\u00A0\u00A0\u00A0\u00A0\u00A0\u00A0 \u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe primary objective of the exploration\r\nwell 34/4 4 was to drill the untested Triassic sequence in the fault blocks\r\nwest of well 34/4-1. The well location was chosen to be stratigraphically\r\nhigher relative to the Triassic sequence in well 34/4-1. The purpose of the\r\nwell location was also to penetrate and core the maximum oil column above the\r\ntentative oil water contact interpreted in well 34/4-1 and to test possible\r\nlateral fluid communication with 34/4-1. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 34/4-4 was spudded with the\r\nsemi-submersible installation Dyvi Alpha on 11 September 1982 and drilled to TD\r\nat 3800 in Middle Triassic sediments, Teist Formation. As much as 15 % of total\r\nrig time was WOW due to bad weather. While coring, after core number 12 was\r\ntaken, the mud was replaced with seawater by accident and caused a kick,\r\nresulting in a 20 bbls influx. The well was drilled with spud mud down to 493\r\nm, with gel mud from 493 m to 1212 m, with gypsum/polymer mud from 1212 m to\r\n2116 m, with Lignosulphonate mud from 2116 m to 2475 m, and with\r\nlignosulphonate/Chem-X mud from 2475 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eFirst oil shows were recorded on cuttings\r\nfrom thin sandstone stringers below 2075 m, accompanied by increased gas\r\nreadings. Sidewall cores from siltstone beds between 2100 and 2414 m also\r\noccasionally had oil shows. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe Early Cretaceous Åsgard Formation rested\r\nunconformably on the Late Triassic Lunde Formation at 2425 m. The Lunde\r\nFormation sandstones were oil bearing down to the oil water contact at 2586 m.\r\nThe OWC was set mostly on the intersection of the oil and water pressure\r\ngradients from RFT data. The oil bearing sand was separated from the water zone\r\nby a 22 m thick ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"41","properties":{"OBJECTID":41,"wlbNpdidWellbore":42,"wlbName":"7/11-5","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eBlock 7/11 was awarded in 1965 to the\r\nPhillips Group. The first commercial discovery (Cod) was found in this block in\r\n1968. Both Norsk Hydro wells (7/11-5 and 7/11-6) were drilled in the\r\nrelinquished area awarded to them in Licence 070. The main objective of well\r\n7/11-5 was the Late Jurassic sandstones. The secondary objective was the\r\nTriassic sands.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 7/11-5 was spudded with the\r\nsemi-submersible installation Treasure Seeker on 9 February 1982 and drilled to\r\nTD at 4478 m in the Triassic Smith Bank Formation. The drilling went forth\r\nwithout incident except for gumbo problems in the top of the 17 1/2"\r\nsection and minor problems with tight hole in the 8 3/8" section. The well\r\nwas drilled with sea water and hi-vis pills down to 615 m and with KCl/Drispac\r\nmud from 615 m to 2115 m. From 2115 m to TD the well was drilled with\r\nKCl/Drispac mud, converted to a fully dispersed gel-lignosulphonate mud in the\r\nlimestone section.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well encountered hydrocarbon bearing\r\nsandstones in the Late Jurassic Ula Formation with a gross sand interval of 86\r\nm between 4155 and 4241 m. An oil water contact has been estimated to be at\r\n4201 m (from logs). RFT pressure measurements and sampling were performed over\r\nthe sandstone interval. Below 4202 m, however, no formation pressures were\r\nobtained due to seal problems caused by bad hole. Thus a contact based on\r\nformation pressure data could not be obtained. The Ula Formation rests\r\nunconformably on the Triassic at 4241 m. In the Triassic, thin stringers of\r\nsandstones were encountered with a total net sand of 2.25 m and an average\r\nporosity of 18%. These sandstones were 100% water saturated. Oil shows were\r\nrecorded from 3694 m in the Late Cretaceous and down to 4217 m in the Ula\r\nFormation. Below 4217 m shows were weak and scattered, and no shows were\r\nreported from the Triassic. \u003c/p\u003e\r\n\r\n\u003cp\u003eFive cores were taken in the Ula\r\nFormation from 4159 m to 4231 m. Cores 1 - 4 bled","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"42","properties":{"OBJECTID":42,"wlbNpdidWellbore":43,"wlbName":"31/4-6","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 31/4-6 was drilled on the Bjørgvin\r\nArch in the Northern North Sea. The main objective was to appraise the 31/4-3\r\nDiscovery in the "Intra-Heather sand II" (Fensfjord Formation) and to\r\ndefine the oil/water contact.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 31/4-6 was spudded with\r\nthe semi-submersible installation Nortrym on 28 February 1982 and drilled to TD\r\nat 2447 m in the Early Jurassic Drake Formation. No significant problem was\r\nencountered in the operations. The well was drilled with seawater and hi-vis\r\nsweeps down to 927 m, with non-dispersed Shale Trol mud from 927 m to 1865 m,\r\nand with a fully dispersed Lignosulphonate/Unical/Ligcon mud from 1865 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe Fensfjord Formation was encountered\r\nat 2150 m. It is a predominantly fine grained to silty, micaceous to very\r\nmicaceous, subarcosic carbonaceous and occasionally glauconitic sandstone with\r\na clay matrix and some heavily calcite cemented stringers. It is 89 m thick and\r\noil bearing from 2156 m down to the OWC at 2172 m. Net pay in the oil bearing\r\ninterval was 12.5 m with an average porosity of 26.4% and an average water\r\nsaturation of 43.8%. As expected the overlying Sognefjord Formation seen in the\r\n31/4-3 and 5 wells was not present at this location. Below the Heather Formation,\r\nthe well penetrated 62.5 m of the Brent Group, which contained 31 m of net sand\r\nwith an average porosity of 23.4% and was water saturated. No other reservoir\r\nintervals were encountered. Occasional poor oil shows were recorded in the Ness\r\nFormation and the Drake Formation.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eFive cores were cut through the Fensfjord\r\nFormation from 2132 m to 2214.5 m. Correlation between the cores and the logs\r\nindicates that core depths are two to thr","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"43","properties":{"OBJECTID":43,"wlbNpdidWellbore":44,"wlbName":"1/9-6 S","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 1/9-6 S was drilled on the\r\nnorth-west flank of the Tommeliten Gamma structure in the Feda Graben in the\r\nsouthern North Sea. The main objective was to appraise the Tommeliten Field.\r\nThe well was drilled deviated due to the planned use of this well as a\r\nproduction well. The main targets were the Ekofisk and Tor formations. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 1/9-6 was spudded with the\r\nsemi-submersible installation Sedco 703 on 21 March 1982. Drilling of the\r\n36" and 26" holes went without incident. There was some difficulty in\r\ngetting logging tools in the 17 1/2" hole. Gumbo problems occurred while\r\ndrilling the 12 1/4" hole and both open hole and cased hole logging runs\r\nwere plagued with tool failures. Differential sticking also occurred while\r\ndrilling the bottom part of the 8 1/2" hole. TD was set 3880 m, 99 m into\r\nthe Late Cretaceous Hod Formation. After retrieving the RFT the well began\r\nflowing and sloughing large amounts of shale below the 9 5/8" shoe. While\r\ncirculating and reaming to TD, the pipe became stuck many times due to shale\r\nsloughing above the bit. A bit and bit sub were left in the hole during these\r\nhole problems, and were never recovered. The well was drilled with\r\n"native" mud/seawater down to 1471 m and with polymer/dispersed\r\nsolids/lignosulphonate/seawater from 1471 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eTop Ekofisk Formation was penetrated at\r\n3411 m (3110 m TVD) and top Tor Formation at 3516 m (3199 m TVD). Both\r\nformations were gas/condensate bearing. No other permeable section in the well had\r\nindications of hydrocarbons.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eA total of 14 cores were cut in the interval\r\n3415.7 - 3619 m in the Ekofisk and Tor formations. Problems with jamming and","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"44","properties":{"OBJECTID":44,"wlbNpdidWellbore":45,"wlbName":"15/9-13","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 15/9-13 was drilled on the Sleipner\r\nEast Field in the Viking Graben in the North Sea. The objective was to\r\ndelineate the hydrocarbon accumulation found in the Heimdal Formation of the\r\n15/9 Gamma structure. Secondary objectives were to test possible hydrocarbons\r\nin sandstones of Jurassic - Triassic age. The well is reference well for the\r\nUtsira and Skade formations. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 15/9-13 was spudded with\r\nthe semi-submersible installation Ross Rig on 21 March 1982 and drilled to TD\r\nat 3280 m in the Permian Zechstein Group. \u003cspan style='color:black'\u003eNo\r\nsignificant problem was encountered in the operations.\u003c/span\u003e The well was\r\ndrilled with seawater and hi-vis slugs down to 518 m, with gel/lignosulphonate\r\nmud from 518 m to 1165 m, gypsum/lignosulphonate mud from 1165 m to 2642 m, and\r\ngel/lignosulphonate mud from 2642 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB style='color:black'\u003eThe well proved gas\r\nand condensate in the Heimdal Formation. Shows on cores indicate that all\r\nsandstones in the Heimdal Formation are gas filled to a probable down-to contact\r\nin top Shetland Group at 2440 m. Gas and condensate were also encountered in a\r\nJurassic sandstone from 2763 to a probable down-to contact at 2791 m. No\r\nhydrocarbons were found in Triassic sandstones. No shows were recorded outside\r\nof the hydrocarbon-bearing sections in the well.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eSeven cores were cut. Cores 1 - 3 were\r\ncut from 2404 m in the Heimdal Formation to 2453.5 m in the Tor Formation with\r\n84 to 100% recovery. Cores 4 - 7 were cut from 2763 m to 2801.6 m in the Hugin\r\nFormation with 90 to 100% recovery. Segregated RFT fluid samples were taken at\r\n2400 m, 2437 m, 2765.8 m, and 2766.5 m.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"45","properties":{"OBJECTID":45,"wlbNpdidWellbore":46,"wlbName":"2/2-1","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 2/2-1 was a wildcat drilled on a\r\nsalt-induced dome structure in the SE corner of block 2/2. The main target was\r\nLate Jurassic sandstone. Secondary targets were pre-Cretaceous sandstones, the\r\nLate Cretaceous Chalk and a sandstone of Oligocene age. According to the\r\nlicense agreement, the well should be drilled into the Triassic, salt or a\r\nmaximum depth of 5000m whatever came first. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe well is Type Well for the Vade\r\nFormation.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eExploration well 2/2-1 was spudded with\r\nthe semi-submersible installation Dyvi Alpha on 9 April 1982 and drilled to TD\r\nat 4003 m in the Late Permian Zechstein Group. When drilling the 36"\r\nsection pipe stuck at 167 m due to a rotary table failure. The well had to be\r\nre-spudded on 11 April. Forty barrels of mud was lost to the formation when\r\ndrilling the 17 1/2" pilot hole in the 26" section. The well was then\r\ndrilled to TD without serious problems apart from various tight spots. The\r\nre-spudded well bore was drilled with sea water and gel down to 207 m, with\r\ngel/gypsum mud from 207 m to 665 m, with polymer/gypsum mud from 665 m to 1448\r\nm, added "Super Shale Trol" shale stabilizer at 1448 m, and drilled\r\nwith lignosulphonate mud from 3260 m to TD. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe well penetrated porous layers in the\r\nOligocene, the Cretaceous and the Upper Jurassic. A full suit of logs was run\r\nin these intervals. In the interval 2100 m to 2171 m of the Oligocene, a sand\r\n(Vade Formation) with good reservoir rock quality was found. The net - gross\r\nratio reaches 0.95 and the porosity nearly 30%. The RFT measurements indicated\r\npermeability in the order of 100 mD. The sand was generally clean, but became\r\nshaly just towards the top. The uppermost part of the sand was gas bearing with\r\na net pay thickness of 8 m and a water saturation of 35%. The GWC was picked at\r\n2111 m from the logs and confirmed by RFT measurements. The reservoir pressure\r\nis approximately 230 bar (3336 psi) at","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"46","properties":{"OBJECTID":46,"wlbNpdidWellbore":47,"wlbName":"25/2-7","wlbHistory":"\r\n\r\n    General \r\n    \r\n    Block 25/2 is located on the eastern margin of the Viking Graben towards the Bjørgvin \r\n    Arch. The main targets for well 25/2-7 were the Middle Jurassic Vestland Group and the \r\n    Early Jurassic Statfjord Formation, which were hydrocarbon bearing in the surrounding \r\n    wells 25/2-4, 25/2-5 and 25/2-6. In addition possible Late Callovian sands, as in the 25/2 \r\n    -4 well, constituted a second target. \r\n    \r\n   \u003cp\u003e\u003cb\u003eOperations and result\u003c/b\u003e\u003c/p\u003e\r\n    \r\n    Wildcat well 25/2-7 was spudded with the semi-submersible installation Borgsten \r\n    Dolphin on 1 April 1982 and drilled to TD at 4110 m in the Early Jurassic Dunlin Group. \r\n    Operations took 103 days including 13 days of down time. Four and a half days were lost \r\n    due to WOW, 5.5 days due to rig compensator damage, and 3 days were lost due to a \r\n    leaking pack off assembly in the 9 5/8\" casing. \r\n    \r\n    No Callovian sands (Intra Heather Formation) were encountered. Of the two main \r\n    objectives the Vestland Group was confirmed and tested as a reservoir. The Vestland \r\n    Group sandstones were encountered at 3406 m, 174 m higher than prognosed. It was \r\n    389 m thick, which was thicker than expected, and it consisted of an upper and a lower \r\n    interval. Massive beds of sandstone, locally slightly shaly or well cemented with some \r\n    layers of black shales and coal were encountered in the upper interval from 3406 m to \r\n    3628 m. The gross thickness of this interval was 222 m and net thickness approximately \r\n    179 m. Porosity as estimated from cores 1 and 2 and logs ranged from 2.5 % to 21 % \r\n    with an average of 12 %. Permeability in this zone was rather low (0.01 to 15.55 mD). \r\n    The second zone was penetrated from 3628 m to 3795 m. This interval was composed \r\n    of shales and sandstones alternating in a regular sequences of 15 to 20 m. Net \r\n    thickness was approximately 77 m with a porosity ranging from 16 % to 21% based on \r\n    logs. Some oil shows were recorded on cores 1 and 2 i","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"47","properties":{"OBJECTID":47,"wlbNpdidWellbore":48,"wlbName":"2/1-4","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 2/1-4 was drilled on the margin\r\nbetween the southern Vestland Arch and the Central Trough in the North Sea. The\r\nfirst well in the block, well 2/1-1 drilled in 1972, was abandoned after taking\r\na kick in the Late Jurassic. The second well, well 2/1-2 drilled in1978\r\nencountered water wet Late Jurassic sandstones. The 2/1-3 well was drilled in\r\n1980 on the downthrown side of a NW-SE trending fault complex and found oil in\r\na 60 m thick Late Jurassic sandstone. A second Jurassic sandstone in 2/1-3 (Ula\r\nFormation) was water wet. The primary objective of the 2/1-4 well was to\r\nappraise the oil in the Late Jurassic "2/1-3 sandstone" (Gyda member).\r\nSecondary objectives were to test the Ula and Bryne Formations and the\r\nTriassic.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well is reference well for the Vidar\r\nFormation.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 2/1-4 was spudded with the\r\nsemi-submersible installation Aladdin on 5 April 1982 and drilled to TD at 4525\r\nm in the Late Permian Zechstein Group. The first and second spuds were\r\nunsuccessful and only the third spud, on 12 April and 60 + 50 ft in direction\r\n315 deg away from the planned location, was successful. The 17 1/2"\r\nsection from 633 to 2006 m and the upper part of the 12 1/4" section were\r\ndrilled with severe swelling shale (gumbo) problems. The well was drilled with\r\nseawater and hi-vis pills down to 633 m, with CMC/gypsum mud from 633 m to 2006\r\nm, and with CMC/gypsum/lignoslulfonate mud from 2006 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 2/1-4 penetrated the top of the Late\r\nJurassic sandstone at 4040 m and the log and core analysis confirmed the\r\nformation to be oil bearing. The log evaluation and core studies showed the Late\r\nJurassic sandstone to consist of two main zone","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"48","properties":{"OBJECTID":48,"wlbNpdidWellbore":49,"wlbName":"7117/9-1","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThe wildcat 7117/9-1 was the first well\r\nto be drilled in the western part of the Troms I area. It is located on the\r\nwestern margin of the Tromsø Basin close to the Senja High. The primary\r\nobjectives of the well were to test two possible sandstone reservoirs of\r\nassumed Late Cretaceous age. Flat spots indicating fluid contacts were noted in\r\neach of these two target horizons. A secondary objective was to test sandstones\r\nof assumed Middle to Early Jurassic age. Planned TD was 2500 m in sediments of\r\nTriassic age.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThe location survey showed the area to be\r\ncovered with iceberg scars with depths from l m to 10 m. The dominant direction\r\nof these scars is ENE-WSW and most of them are filled with sand and silt. The\r\nquaternary sediments were about 280 m thick and layered in three main zones.\r\nThere were no indications of shallow gas in the area.\u003c/p\u003e\r\n\r\n\u003cp\u003eExploration well 7117/9-1 was spudded\r\nwith the semi-submersible installation Treasure Scout on 20 April 1982. Due to\r\nexcessive hole deviation while drilling to 303 m the rig had to be moved to\r\nrespud the well on 24 April. In this attempt high torque in extremely hard top\r\nlayers caused the drill string to twist off at 299 m. The third hole was\r\nspudded on 30 April. The drilling progressed without further problems. The last\r\nsection was drilled with 8 3/8" bit and the well reached TD at 3200 m in\r\nEarly Cretaceous (Middle Albian to ?Aptian) clay stone. The well was drilled\r\nwith seawater and hi-vis pills down to 348 m, with seawater/bentonite from 348\r\nm to 817 m, and with gypsum / lignosulphonate from 817 m to 1220 m. From 1220 m\r\nthe mud was changed to a gel lignosulphonate system as the reactive clays\r\ndisappeared and the rest of the well was drilled with this mud system.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe more shallow of the two Late\r\nCretaceous target reservoirs was found to be a low velocity clay stone interval\r\nof Paleocene age, between 1277 m and 1328.5 m. The flat spot (at 1.4 sec TWT)\r\ncou","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"49","properties":{"OBJECTID":49,"wlbNpdidWellbore":50,"wlbName":"7120/8-2","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThe 7120/8-2 well was drilled on the\r\nAlpha-South structure in the Western part of the Hammerfest Basin. The first well in the block, well 7120/8-1, was drilled on the Alpha North closure in\r\n1981, north of the major east - west fault splitting the two\r\nclosures/structures. This well found gas-bearing sandstones in the Middle to\r\nEarly Jurassic. The primary objective of well 7120/8-2 was to test possible\r\nhydrocarbon accumulations in sandstones of Middle to Early Jurassic age (Stø Formation)\r\nin the Alpha-South structure. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 7120/8-2 was spudded with the\r\nsemi-submersible installation Neptuno Nordraug on 15 April 1982 and drilled to\r\nTD at 2590 m in Late Triassic sediments (Fruholmen Formation). The drilling of\r\nthe 36" and 26" hole went forth without any problems. After this\r\nseveral problems occurred and 78 days were used to reach TD, 29 days more than\r\nprogrammed. The main hang-ups were: broken 20" csg, partly collapsed\r\n13-3/8" csg, pulled BOP stack, roller system, and stucked stabilizer at\r\n2156 m. The well was drilled with gel/spud mud down to 333 m, with gel/seawater\r\nfrom 333 m to 752 m, and with gel/lignosulphonate/seawater from 752 m to TD. \u003c/p\u003e\r\n\r\n\u003cp\u003eHydrocarbon accumulations were discovered\r\nin sandstone sequences between 2081-2161 m in the Stø Formaton. The reservoir\r\nsandstones showed good to excellent reservoir properties. Gas composition from\r\nthe DST was almost identical to the gas composition of the DSTs performed in\r\nthe 7120/8-1 well. This was also indicated by gas gradients established from\r\nthe RFT pressure points taken in the two wells. RFT pressure points from the\r\ntwo wells also indicated that the water zone most likely is in communication.\r\nOrganic geochemical analyses show TOC in the range 0.7 % to 2.8 % TOC in mudstones\r\nfrom the Early Cretaceous. The kerogen in these samples are Type IV / III with\r\na poor potential, increasing to fair at the base, for gas. Olive black\r\nclaystones o","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"50","properties":{"OBJECTID":50,"wlbNpdidWellbore":51,"wlbName":"6507/11-2","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 6507/11-2 was drilled as the\r\nfourth well offshore Mid-Norway in the Møre/Trøndelag II area. The well was\r\ndrilled on a symmetric, north-south trending horst called Y-1 in the\r\nnortheastern part of the block, where seismic line SG 8158-401 indicated a\r\npossible minor rollover trending north-south at the Base Cretaceous level. The\r\nobjective of well 6507/11-2 was to test the stratigraphic sequence below the\r\nTop Palaeocene reflector. The targets, represented by expected minor vertical\r\nclosures, were sandstone reservoirs of Early - Middle Jurassic age. The\r\nentrapment of major petroleum accumulations was dependent upon a lateral\r\nsealing mechanism in the northern part of the Y-l horst.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 6507/11-2 was spudded with the\r\nsemi-submersible installation West Venture on 18 April 1982 and drilled to TD\r\nat 2905 m in the Late Triassic Grey Beds. No significant problems were\r\nencountered during operations. The well was drilled with seawater and slugs of\r\nspud mud down to 412 m, with gypsum mud from 412 m to 857 m, with\r\n"Pro-mud" gypsum polymer mud from 857 m to 1775 m, and with\r\nLignosulphonate mud from 1775 m to TD. In the Jurassic and Triassic section\r\nfrom 1898 to TD, sandstones with a total net porous sand thickness of 395 m was\r\nfound. They were all water bearing. The Net-Gross ratio of the Jurassic\r\ninterval, 1898-2622 m is 0.45. The Middle/Early Jurassic Ile Formation\r\n(1948-2040 m) was fine to medium grained and well sorted sandstone. A net sand\r\nthickness of 65 m was defined in Ile, with porosity of 31% and permeabilities\r\nranging from 100 mD to 28 D. The upper part was clean and showed extremely good\r\nreservoir rock properties. The lower part of the sand contained significant\r\namounts of mica. Although this part was less permeable than the top, this too\r\nwas a very good reservoir rock. The Early Jurassic sand (2117 - 2289 m) was\r\nless sorted than the Middle Jurassic sand. It was very fine grained and\r\ncontai","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"51","properties":{"OBJECTID":51,"wlbNpdidWellbore":52,"wlbName":"15/3-5","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 15/3-5 was drilled on the Gudrun\r\nTerrace, east of the 15/3-1 S Gudrun Discovery in the North Sea. Well 15/3-5\r\nwas drilled in a downdip position of a structure explored by the well 15/3-4,\r\nwhere oil bearing reservoirs of Middle Jurassic age were tested. The main\r\nobjectives of 15/3-5 were to find the extension of these reservoirs and to\r\ndefine a hydrocarbon/water contact. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 15/3-5 was spudded with\r\nthe semi-submersible installation Byford Dolphin on 28 December 1983 and\r\ndrilled to TD at 4130 m in the Middle Jurassic Sleipner Formation. Drilling was\r\nsuspended at 195 m due to bad weather. The well was re-spudded on 6 January 25\r\nm west of the original location. Some technical problems with the BOP occurred\r\nafter setting of the 20" and 13 3/8" casings. A seat protector got\r\nstuck in the riser during drilling of the 17 1/2" hole. Drilling breaks\r\noccurred at 3943 m, 3954 m, 4018 m, 4032 m and at 4041 4043 m in the 8 1/2"\r\nhole section. The well was drilled using water based mud.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eTop Draupne Formation was encountered at\r\n3808 m, followed by the Heather Formation at 3881 m, and the target Middle\r\nJurassic Sleipner Formation at 3935 m. Several thin reservoir zones were\r\npenetrated in the Sleipner Formation. The sands were interpreted as minor\r\nfluvial channels (2 to 5m in thickness) deposited in two main sequences. Four\r\nof the channels were oil-bearing with an oil gradient of 0.61 bar/10 m based on\r\npressure measurements. An OWC could be established at 4022.6 m. Pressure\r\nmeasurements showed that the upper fluvial channel sequence is over-pressured,\r\nand not in contact with the sands encountered in well 15/3-4. The lower fluvial\r\nsequence could be connected between the two wells. Petro","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"52","properties":{"OBJECTID":52,"wlbNpdidWellbore":53,"wlbName":"30/6-14","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 30/6-14 was drilled on the Zeta\r\nstructure on the Brage Horst, east of the main Oseberg Alpha structure and\r\nsouth of the Oseberg Beta structure. The primary objectives for the well were\r\nto find hydrocarbons in the Brent Group, and to find additional hydrocarbon\r\naccumulations within possible Early and Late Jurassic sandstone deposits. Planned\r\nTD of the well was ca 3100 m or 75 m into the Statfjord Formation.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 30/6-14 was spudded with the\r\nsemi-submersible installation Treasure Scout on 17 December 1983 and drilled to\r\nTD at 2900 m in the Early Jurassic Statfjord Group. No significant problems\r\noccurred in the operations. The well was drilled using water based mud. The\r\nwell was drilled with spud mud down to 618 m, with KCl/polymer mud from 618 m\r\nto 1675 m, \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eTop Brent Group was penetrated at 2650 m\r\nand top Drake Formation at 2589 with an Intra Drake Sand at 2605 to 2621 m.\r\nBoth Brent and Drake were found water bearing. Hydrocarbons were encountered in\r\nthe top of the Early Jurassic Statfjord Group from 2783.5 m down to a depth of\r\n2789 m. RFT pressures indicated the free water level to be at 2790 m. No\r\nadditional hydrocarbon bearing reservoirs were encountered. Apart from spots of\r\ncut fluorescence on claystones in the Drake Formation no oil shows were\r\nrecorded outside of the Statfjord Group hydrocarbon bearing reservoir. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThree cores were cut in the Jurassic\r\nsequence, one from 2561 to 2567.6 m in the Etive Formation, one from 2608 to\r\n2621.2 m in the Drake Formation, and one from 2785 to 2800 m in the upper part\r\nof the Statfjord Group. No wire line fluid samples were taken.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was permanen","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"53","properties":{"OBJECTID":53,"wlbNpdidWellbore":55,"wlbName":"30/9-3","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 30/9-3 was drilled on the Gamma West\r\nstructure on the Oseberg Fault Block in the northern North Sea. The primary\r\nobjective was to find hydrocarbon accumulations in the Middle Jurassic Brent\r\nGroup. Secondary objective was to find additional hydrocarbon accumulations in\r\nthe Early Jurassic. Planned TD was ca 75 m below a possible intra Triassic\r\nmarker to a depth of 4188 +/- 100 m\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 30/9-3 was spudded with the\r\nsemi-submersible installation Nortrym on 31 December 1983. The well was drilled\r\nto a depth of 3113 m into Drake Formation shales where the pipe got stuck and\r\nparted when pulling out of hole for logging. The fish was not recovered and no\r\nwire line logs were recorded below 1713.5 m due to fish in hole. All lithostratigraphic\r\ninterpretation below this point is therefore based on cuttings description,\r\ncore description, chromatograph data and ROP information. A sidetrack was\r\ndecided to complete the well programme. The well was drilled with spud mud down\r\nto 625 m and with Invermul/EZmul Oil Based Mud from 625 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe Brent Group (2712-3045 m) consisted\r\nof a 259 m thick Ness Formation (2712 - 2971 m) made up of sandstones with stringers\r\nof shale, siltstone and coal and 74 m of Etive Formation (2971 - 3045m)\r\nsandstones. Based on chromatograph analysis on hydrocarbon samples extracted\r\nfrom core samples a GOC was found at ca 2734 m and an OWC at ca 2815 m, both\r\nlocated in the Ness Formation. From core and chromatograph data the Ness\r\nFormation had a gross pay of 103 m. The net gas pay was estimated to 22 m and\r\nthe net oil pay to 36 m giving a total net pay of 58 m (cut off values porosity\r\n< 12%, permeability < l mD). The average porosity was calculated from\r\ncores to 22.5 % and average","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"54","properties":{"OBJECTID":54,"wlbNpdidWellbore":56,"wlbName":"30/6-10 A","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 30/6-10 A is a sidetrack to\r\nappraisal well 30/6-10 on the Alfa structure on the Oseberg Field in the North\r\nSea. The primary well found oil and gas all through the Brent Group with a\r\ngas/oil contact at 2520 m, but no oil water contact. The main objective was to further\r\ndefine the gas/oil contact and to perform drill stem tests over the reservoir. The\r\nwell was planned to penetrate the Brent reservoir approximately 300 m west of\r\nthe original hole.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 30/6-10 A was sidetracked\r\non 2 December 1982 through a milled window in the 13 3/8" casing at 1788\r\nto 1803 m in the primary well bore. The sidetrack was drilled with the\r\nsemi-submersible installation Treasure Scout to 2665 m (2577 m TVD) in the Early\r\nJurassic Drake Formation. At 2657 m bad weather came up and caused some\r\nproblems and down time. The pipe got stuck at TD but was worked free after 32.5\r\nhrs using pipe lax, Imco spot and diesel. Otherwise the sidetrack was drilled\r\nwith KCl/polymer mud from kick-off to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eFirst oil shows were seen in cuttings\r\nfrom limestone stringers in the Balder Formation at 2015 m. Oil shows on\r\nlimestone cuttings continued down through the Shetland Group to top Heather\r\nFormation at 2448 m. The Brent Group interval from 2480 - 2608.5 m (2429 - 2531\r\nm TVD) was found hydrocarbon bearing over the entire interval with the free\r\ngas/oil contact based on RFT pressure gradients at 2594 m (2520 m TVD) in the\r\nNess Formation. No oil/water contact was found. The net pay in the Brent Group was\r\ncalculated to be 58 m with average porosity of 24.4% and average water\r\nsaturation of 27%. The net/gross ratio in 30/6-10 A is higher than in 30/6-10\r\ndue to a better sand development in the Ness Formation. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=M","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"55","properties":{"OBJECTID":55,"wlbNpdidWellbore":57,"wlbName":"7/11-7","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThe primary objective of the wildcat\r\n7/11-7 S was Late Jurassic sandstone surrounding a small salt piercement below\r\nthe Paleocene Cod Field reservoir. Several discoveries had been made in the\r\nvicinity of Cod, in the Upper Jurassic Ula Formation. The Triassic and Permian\r\nconstituted secondary targets. The well was drilled from the Cod platform with\r\nplanned bottom hole location ca 0.9 km to the east. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 7/11-7 S was spudded from\r\nthe fixed installation Cod on 29 December 1982 and drilled deviated to TD at\r\n4927 m (4661 m TVD) m in the Late Permian Zechstein Group. The well was\r\nscheduled as a 150-day project but a full drilling crew was still present on\r\nday 349 and it took until day 364 to set a plug above the last set of\r\nperforations. The length of this project was due to problems in drilling and\r\nextended testing to adequately evaluate the three zones of interest. There were\r\ndelays in setting plugs, running casing, fishing, and installing necessary 10,000\r\npsi surface equipment. The testing delays included problems with setting\r\nDHSV's, parted tubing, aborted stimulations, bad weather, and bailing\r\noperations. The well was drilled with seawater/lignite and Desco, an organic\r\nthinner. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe well reached all three targets. Late\r\nJurassic Ula Formation sandstone was encountered at 4527 m. The Ula Formation\r\nrested unconformable on Triassic Skagerrak Formation sandstone at 4566 m. The\r\nPermian Zechstein dolomites were encountered at 4856 m. Good shows were\r\nrecorded in the Ula Formation, with weaker shows extending down to 4609 m in\r\nthe Triassic Skagerrak Formation. A second Triassic zone with weak shows was\r\nobserved at 4785 m to 4810 m. Source rock formations were found in the Tertiary\r\ninterval from 1820 m to 2500 m, and in the Late Jurassic shales of the Mandal\r\nand Farsund Formations at 4405 m to 4527. The Tertiary interval had TOC in the\r\nrange 2 - 4 %, Hydrogen Index from 100 to 120 mg HC/g rock, and was ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"56","properties":{"OBJECTID":56,"wlbNpdidWellbore":58,"wlbName":"30/6-11","wlbHistory":"\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 30/6-11 was drilled on the Delta\r\nstructure on the Flatfisk Slope, close to the northwestern end of the Oseberg\r\nFault Block in the North Sea. The primary objective was to find hydrocarbon\r\naccumulations in the Brent Group. Secondary objective was to find additional hydrocarbon\r\naccumulations within the Early Jurassic Cook Formation and Statfjord Group. The\r\nwell was placed in an area where a complete Jurassic succession could be\r\nexpected. Planned TD was 75 m into the Statfjord Group.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 30/6-11 was spudded with the\r\nsemi-submersible installation Nortrym on 20 December 1982 and drilled to TD at 4001\r\nm in the Early Jurassic Statfjord Group. When running casing in the 17\r\n1/2" section at 2165 m the rig had to wait on weather. Cavings accumulated\r\nas fill on the bottom and the casing was differentially stuck. Various\r\nadditives were used to free the casing, including diesel. The well was drilled\r\nwith seawater and hi-vis pills down to 235 m, with pre-hydrated bentonite and\r\nseawater from 235 m to 965 m, and with KCl/polymer mud from 965 m to 2165 m.\r\nFrom 2165 m to 3654 m, the KCl/polymer mud was slowly converted to a dispersed\r\nlignosulphonate/lignite mud and in the bottom 8 3/8" section, from 3654 m\r\nto TD a dispersed lignosulphonate/lignite mud system was used. From 2165 and\r\ndownwards the diesel content in the mud was 5%, diminishing to traces below\r\n3265 m.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe Brent Group (3351 - 3561m) had a\r\ngross thickness of 210 m with 118 m of net sand, giving a net to gross ratio of\r\n0.56. The average porosity of the sandstones were calculated from wireline logs\r\nto 16% with an average water saturation of 80%. The Cook Formation (3752.5 -\r\n3768.5m) had a net sand thickness of 3 m, giving a net to gross ratio ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"57","properties":{"OBJECTID":57,"wlbNpdidWellbore":59,"wlbName":"34/10-16","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 34/10-16 was drilled on the Gullfaks\r\nSør structure, 8 km south of the Gullfaks Field. The purpose of this well was\r\nto investigate a fault block, en echelon to the first fault block tested by\r\nwell 34/10-2, for possible extension of hydrocarbon accumulation. The principal\r\ndrilling objective was sandstones of the Brent Group. Secondary objectives were\r\nthe Cook and Statfjord sands, of which the Statfjord sand proved the presence\r\nof oil in well 34/10-2. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 34/10-16 was spudded with\r\nthe semi-submersible installation Nordraug on 14 December 1982 and drilled to\r\nTD at 4042 m (4027 m TVD) in the Late Triassic Lunde Formation. Excessive time\r\nwere lost due to waiting on weather, hole problems, logging problems and other\r\ntechnical problems. These problems consumed a total of 1080 hours or 45 days\r\ndowntime. The well was drilled with spud mud down to 225 m, with gel/seawater\r\nfrom 225 m to 617 m, and with lignosulphonate CMC/gel mud from 617 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe Brent Group came in at 3171 m and contained\r\nboth oil and gas with the gas/oil contact at ca 3350 m and the oil/water\r\ncontact at ca 3422 m, according to the logs. The gas net pay was estimated to\r\n84 m with average porosity 18.2% and average water saturation 22.5%. The oil\r\nnet pay was estimated to 29.5 m with average porosity 16.5% and average water\r\nsaturation 38.9%. No hydrocarbons were encountered in the Cook and Statfjord\r\nFormations. No oil shows were recorded outside of the Brent Group. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eA total of 23 cores were cut, 22 of these\r\ncovering nearly all of the Brent Group and the last one covering a sandstone in\r\nthe upper Statfjord Formation. The RFT tool was run for fluid samples.\r\nSegregated RFT sample","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"58","properties":{"OBJECTID":58,"wlbNpdidWellbore":60,"wlbName":"15/9-17","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 15/9-17 was drilled on the Sleipner\r\nTerrace in the Viking Graben of the North Sea. The primary objectives were to\r\ntest possible hydrocarbon accumulations in the Paleocene Heimdal Formation and\r\nin Jurassic/Triassic sandstones. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 15/9-17 was spudded with the\r\nsemi-submersible installation West Vanguard and drilled to 3120 m in the\r\nTriassic Smith Bank Formation. A 12 1/4" pilot hole was drilled down to\r\n519 m, but no indications of shallow gas was found. Bad weather caused some\r\ndelay. Bad weather and repeated BOP problems caused some down time. The well\r\nwas drilled with spud mud down to 500 m, with gypsum/polymer mud from 519 m to\r\n2616 m, with Lignosulphonate/Drispac mud from 2616 m to 2950 m, and with\r\nDrispac from 2950 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eBoth the Heimdal Formation and the\r\nMesozoic sandstones contained gas and were tested. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe log evaluation indicated top of the\r\nhydrocarbon column in the Heimdal Formation at 2377.5 m. The logs indicated the\r\ngas/water contact at 2418.5 m, while pressure data gave a gas/water contact a\r\nbit shallower, at 2413 m. Weak and spotted shows were recorded on cored\r\nsandstones in the Heimdal Formation below the contact down to 2425 m, and from\r\n2442 to 2450 m.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe top of the hydrocarbon column in the\r\nMesozoic sandstones was at 2715 m (top Vestland Group). The column extended\r\ndown into the Triassic. No definite gas/water contact was found but could be as\r\ndeep as 2848 m. Shows were recorded on cored sandstones throughout this\r\nreservoir, getting weaker with depth. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo shows were seen outside of the\r\nhydrocarbon bearing sectio","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"59","properties":{"OBJECTID":59,"wlbNpdidWellbore":61,"wlbName":"6407/1-2","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThe wildcat 6407/1-2 was drilled 43 m NW\r\nof well 6407/1-1, which was drilled to 900 m before it was junked due to\r\nproblems with setting the 20" casing. The objective for both wells was to\r\ntest for hydrocarbons in Jurassic sandstones. The primary target was Middle\r\nJurassic sand horizons, Early Jurassic sands was secondary target. The well was\r\nthe first well north of 62 degrees to encounter liquid petroleum.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well is Type Well for the Kai\r\nFormation and Reference Well for the Nordland Group. It is Reference Well for\r\nthe Lyr Formation, the Fangst Group, and the BÅt Group\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 6407/1-2 was spudded with\r\nthe semi-submersible installation Dyvi Delta on 13 November 1982 and drilled to\r\nTD at 4560 m in the Late Triassic Grey Beds. The well was drilled with\r\nseawater/gel down to 901 m, with gypsum/lignosulphonate from 901 m to 3568 m,\r\nand with Spersene/XP-20/resin from 3568 m to TD. At 1817 m loss of mud to the\r\nformation was discovered. A survey showed that this was caused by a collapse of\r\n20" casing from approximately 667 m. It was therefore decided to run the\r\n13 3/8" casing at this point. A total of 164 days were spent on the\r\ndrilling phase, which was 56 days more than prognosed. 22 days were lost due to\r\nbad weather, 17 days due to BOP problems, 4 days working with the collapsed\r\n20" casing, 7 days were spent on fishing when the drill string parted. A\r\nfurther 12 days were spent on excessive reaming in the 12 1/4" hole in the\r\nPaleocene and top of the Cretaceous formation, and in the 8 1/2" hole in\r\nthe Heather formation. The reaming was necessary when running back in hole\r\nafter several days WOW with the BOP closed and the riser disconnected. The well\r\nwas drilled 60 meters deeper than prognosed. The testing phase lasted for 21\r\ndays, which includes a 7" casing tie back operation of 6 days, which was\r\nnecessary because of a leak in the 9 5/8" at approximately 1850 m. The","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"60","properties":{"OBJECTID":60,"wlbNpdidWellbore":62,"wlbName":"30/11-3","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 30/11-3 was drilled in the Fensal\r\nsub-basin in an area east of the Frigg and Odin Fields in the North Sea. The\r\nprimary objective was to test Middle Jurassic sandstones of the Brent Group and\r\nEarly Jurassic sandstones of the Statfjord Group in a westward tilted horst block.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well is type well for the Hardråde\r\nFormation and reference well for the Svarte, Tryggvason and Kyrre formations.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 30/11-3 was spudded with the\r\nsemi-submersible installation Borgny Dolphin on 17 November 1982 and drilled to\r\nTD at 4662 m in the Early Jurassic Statfjord Group. When entering sandstones in\r\nthe Statfjord Group at 4637 m the well kicked, probably due to overpressured\r\ngas. After efforts to stabilise the well the decision was made to abandon the\r\nwell before a full evaluation of the Statfjord Group had been made. The well\r\nwas drilled with spud mud down to 640 m, with KCl/polymer mud from 640 m to\r\n3053 m, and with Drispac/lignosulphonate - gel/Resinex mud from 3053 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 30/11-3 encountered reservoir\r\nquality sands in the Tertiary (Frigg Formation and Heimdal Formation) and in\r\nthe Jurassic (Brent Group and Statfjord Group). Oil saturations were seen in\r\nseveral thin sands in the Brent Group between 3434 m and 4025 m. Core and log\r\nevaluation indicated that these were probably due to residual oil only\r\n(saturations below a cut-off value of 50%). True oil shows were recorded\r\nintermittently only between 3434 m and 3600 m. Possible pay zones with\r\nreasonable porosity and permeability would be thin, with a net of only 13 m\r\nbased on petrophysical evaluation. Log evaluation also indicated high gas\r\nsaturations (up to more than 80%) in the Statfjord Group. However","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"61","properties":{"OBJECTID":61,"wlbNpdidWellbore":63,"wlbName":"2/1-5","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 2/1-5 was drilled on the Cod Terrace\r\nof the Central Graben in the southern North Sea. The primary objective was test\r\na Late Jurassic sandstone prospect on the south side of a large, central salt\r\nculmination in block 2/1. The prospect was developed by analogy with the 2/1-3\r\noil discovery (Gyda) on the north-western slope of the same salt high. There,\r\nthe reservoir is a 60 to 90 m thick sand within the Farsund formation, with closure\r\nformed primarily by pinch out/truncation beneath the Mandal Formation on\r\nlapping on the central salt high. Secondary objectives were possible deeper\r\nreservoirs such as the Ula and Bryne Formations and the Triassic down to top\r\nsalt.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 2/1-5 was spudded with the\r\nsemi-submersible installation Sedco 707 on 13 November 1982 and drilled to TD\r\nat 4454 m. In the Cretaceous sequence the string got stuck and the well had to\r\nbe sidetracked from 2882 m. After a drilling break at 4186 m an oil kick occurred\r\nwith 21.5 m influx and oil appearing in the mud. RFT measurements in sandstone\r\nunits below the oil kick showed pore pressures on a gradient equivalent to a\r\nmud weight of 2.10 g/cm. This gave little margin for safe onward drilling to\r\nTop Salt and the well was terminated in dark, carbonaceous mudstone of\r\nuncertain, possibly Early Jurassic age. The well was drilled with seawater/gel\r\ndown to 635 m, with gypsum/lignosulfonate mud from 635 m to 3830 m, and with\r\nLignosulphonate/lignite mud from 3830 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 2/1-5 reached the Base Cretaceous Unconformity\r\nand the "Hot shale" at 3882 m as predicted. Coring was initiated when\r\ntraces of sand were observed near the predicted "top reservoir", but\r\nonly dark, carbonaceous mudstone/siltstone was recovered. In ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"62","properties":{"OBJECTID":62,"wlbNpdidWellbore":64,"wlbName":"2/6-3","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 2/6-3 is located on the north western\r\nflank of the Mandal High between the Søgne Basin and the Central Graben in the\r\nNorth Sea.It was drilled to\r\ntest possible hydrocarbon accumulations in Late and Middle Jurassic sandstones.\r\nA third objective was to reconnoitre below base Permian.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 2/6-3 was spudded with the\r\nsemi-submersible installation Byford Dolphin on 9 November 1982 and drilled to\r\nTD at 4060 m, 270 meter into pre-Late Devonian basement rock. Technical\r\nproblems occurred in the 12 1/4" section due to twist-off of Kelly saver,\r\nloss of 2700 m logging cable in hole, and 9 5/8" casing hanger collapse,\r\ncausing a total of 203 hrs lost time. In the 8 1/2" section an anchor\r\nchain parted during a storm and four days were lost waiting on weather and\r\nre-anchoring. The well was drilled with water based mud.\u003c/p\u003e\r\n\r\n\u003cp\u003eIn the Late Jurassic only marine shales\r\nwere encountered. At 3545 m, 200 m higher than prognosed a Middle Jurassic,\r\nfluvial sandstone of Bajocian age (Bryne Formation) was found water bearing. A\r\nsequence of anhydrite, dolomite and pure anhydrite was found below the Triassic\r\nred-shales, but no salt or Rotliegendes reservoir rocks were encountered. The\r\nPermian anhydrite was followed by a series of slated shales and phyllitic\r\nrocks, getting progressively more and more deformed, and with an introduction\r\nof metamorphism towards TD. Rb-Sr dating on 1-micron fraction material from\r\n3875 m gave an age of 376 Ma in the Late Devonian. No oil shows were reported\r\nfrom the well. Background gas was recorded down to top Permian. No gas was\r\nrecorded below top Permian.\u003c/p\u003e\r\n\r\n\u003cp\u003eThree cores were cut. K1was cut at 3551 -\r\n3560 m in Bryne Formation sandstone with 85% recovery. K2 was cut at 3886 -\r\n3895 m in basement rock with 11% recovery (one meter, presumed to be from the\r\ntop of the interval), and K3 was cut in basement at TD with 58% recovery. RFT\r\npressure points were obtained but no wire l","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"63","properties":{"OBJECTID":63,"wlbNpdidWellbore":65,"wlbName":"30/9-1","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 30/9-1 was drilled on the southeast\r\npart of the Oseberg fault block (Alpha structure) in the North Sea. The Alpha structure\r\nis an eastward tilted fault block that contains proven reserves of oil and gas\r\nin the Middle Jurassic Brent Group sandstone reservoir. The primary objective\r\nof the well was to establish the oil/water contact in this part of the\r\nstructure.\u003cb\u003e \u003c/b\u003eThe well was planned to be drilled to a total depth of 2850 m,\r\napproximately 100 m into the Dunlin Group.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 30/9-1 was spudded with\r\nthe semi-submersible installation Treasure Seeker on 24 October 1982 and\r\ndrilled to TD at 2895 m in the Early Jurassic Drake Formation. No significant\r\nproblem was encountered in the operations. The well was drilled with\r\nseawater/hi-vis pills and pre-hydrated bentonite down to 969 m, with\r\nKCl/Drispac mud from 969 m to 2515 m, and with KCl/polysal mud from 2515 m to\r\nTD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe Brent Group was found hydrocarbon\r\nbearing from 2685 m down to 2738 m where the free water level was established.\r\nThis interval comprises the whole of the Ness Formation and the uppermost 3 m\r\nof the Etive Formation. Net pay in the interval was 10.5 m. Poor oil shows were\r\nrecorded on limestone cuttings in the interval 2281 to 2232 m in the uppermost\r\nShetland Group. Good oil shows were recorded through the oil column of the\r\nreservoir. Below the contact at 2738 m, shows became weaker and patchy down to\r\n2778 m. Below this depth only some weak shows on claystone from three sidewall\r\ncores in the interval 2872 m to 2895 m were reported.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eSeven conventional cores were cut from 2682\r\nm at the top of the Ness formation to 2784.9 m, into the Dunlin Group shales. RFT\r\nfluid samples were ta","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"64","properties":{"OBJECTID":64,"wlbNpdidWellbore":66,"wlbName":"6407/1-1","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eExploration well 6407/1-1 is located on\r\nthe Halten Terrace off shore Mid Norway. The purpose of the well was to test\r\npossible hydrocarbon accumulations in sandstones of Middle and Early Jurassic\r\nage.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 6407/1-1 was spudded with the\r\nsemi-submersible installation Dyvi Delta on 19 October 1982 and drilled to TD\r\nat 900 m in Pliocene sediments (Nordland Group). The well was drilled with\r\nseawater/gel all through. Due to problems with setting of the 20" casing, the\r\nhole was plugged and abandoned on 13 November 1982. Spudding and drilling of\r\nreplacement well 6407/1-2 started the same day.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was performed\u003c/p\u003e\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"65","properties":{"OBJECTID":65,"wlbNpdidWellbore":67,"wlbName":"34/10-15","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 34/10 15 was drilled as a wildcat on\r\na horst block in the south-eastern part of the Gullfaks Field. The primary\r\npurpose of the well was to test hydrocarbon accumulations in the Jurassic and\r\nBrent sands. Secondary objectives were the Early Jurassic Statfjord sands and\r\nto test shallow gas accumulations in Pliocene sands.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 34/10-15 was spudded with\r\nthe semi-submersible installation Neptuno Nordraug on 16 October 1982 and\r\ndrilled to TD at 2400 m in Late Triassic sediments in the Statfjord Group. A 12\r\n1/4” pilot hole was drilled from 250 m to 950 m to check for shallow gas. The\r\nwell was situated ca 90 m south of the location for the well 34/10-10, which\r\nwas abandoned due to gas flow from a gas filled sand at 428 m. The same\r\nsandlense was penetrated in the well 34/10-15 from 444-447 m. The well was\r\ndrilled with spud mud down to 250 m and with gel/seawater/lignosulphonate mud\r\nfrom 250 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWeak shows on cuttings, mostly on\r\nlimestone, were recorded intermittently from 1220 m in the Hordaland Group to\r\n1630 m in the Lista Formation. The Brent Group sands were not encountered. Late\r\nTriassic Statfjord Group sands were found water wet without shows. The Cook Formation\r\nsands contained residual oil. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eTen cores were cut. Cores 1 to 5 were cut\r\nfrom 1870 m to 1945 m in the Cook Formation with recoveries varying from 34% to\r\n75%. Cores 6, 7, and 8 were cut from 2170 m to 2213 m in the Amundsen Formation\r\nwith recoveries varying from 87% to 93%. Cores 9 and 10 were cut from 2301 m to\r\n2323 m in the Statfjord Group with 90% and 85% recoveries, respectively. An RFT\r\nfluid sample was taken at 1875.5 m in the Cook Formation residual oil zone. The\r\nsample co","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"66","properties":{"OBJECTID":66,"wlbNpdidWellbore":68,"wlbName":"6507/11-1","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 6507/11-1 is located in the\r\nHaltenbanken area and was the third well to be drilled off shore Mid Norway.\r\nThe purpose of drilling the well was to test the whole stratigraphic sequence\r\nbetween seabed and 500 metres below the Near-Base Jurassic reflector or into\r\nthe Triassic, whichever came first.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe specific targets, represented by\r\nvertical closures, were Middle Jurassic sandstone, below the Base Cretaceous\r\nUnconformity, and Early Jurassic sandstone below the Middle Jurassic\r\nUnconformity. A possible flatspot was identified at this level. In addition,\r\nany horizon below these reflectors will, according to Saga's interpretation, be\r\nclosed, and represent a possible reservoir.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well is Type Well for the Tilje\r\nFormation.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 6507/11-1 was spudded with the\r\nsemi-submersible installation West Venture on 13 September 1981 and drilled to\r\nTD at 3139 m in the Late Triassic Grey Beds. Two gas kicks occurred in the 12\r\n1/4" section at 2125 m and 2128 m with up to 600 000 ppm gas readings\r\nobserved at surface. The blow out was killed by circulating increasing mud\r\nweight in steps from 11.0 ppg to 13.2 ppg. The well was drilled with spud mud\r\ndown to 460 m, with gypsum mud from 460 m to 815 m, with gypsum/polymer mud\r\nfrom 815 m to 1615 m, and with a lignosulphonate/causticized-lignite mud\r\nthrough the 12 1/4" section from 1615 m to 2300 m. In this section a\r\nnumber of mud additives were used in the kill well operations. The section from\r\n2300 m to TD was drilled with a lignosulphonate mud.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well proved the existence of a\r\nlithological sequence ranging in age from Late Triassic (Early Rhaetian) to\r\nQuaternary. The Cenozoic succession was 1794 m thick. The dominant lithology of\r\nthe Nordland and Hordaland Group was clay stone, but the former was less\r\nconsolidated and contained more poorly sorted sand and rock fragments. An\r\nargillaceous sandstone of Oligocene/Miocene age was encounte","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"67","properties":{"OBJECTID":67,"wlbNpdidWellbore":69,"wlbName":"15/9-10","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well is located between the\r\nSleipner Vest and Sleipner Øst Fields. The well was designed to test possible\r\nhydrocarbon accumulations in the Upper Middle Jurassic sands and secondary test\r\nHeimdal Formation Sand of Paleocene age.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 15/9-10 was spudded with the\r\nsemi-submersible installation Neptuno Nordraug on 15 September 1981 and drilled\r\nto TD at 3289 m in the Triassic Smith Bank Formation. Drilling the 26"\r\nhole section complete loss of returns occurred at 186 m and a cement plug was\r\nset. Drilling out of the cement returns were again lost, at 178 m, requiring a\r\nfurther cement plug. Total losses due to this loss zone were well in excess of\r\n10 000 bbls. After this operations went without significant problems. The well\r\nwas drilled with seawater and hi-vis pills down to 172 m. The next section, the\r\n26" section, was drilled down to 472 m with seawater/bentonite and\r\nquantities of Mica Fine, Nutplug, Kwikseal, and other additives. From 472 m to\r\nTD m the well was drilled with polymer/Drispac.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well encountered Tertiary sands in\r\nthe Utsira Formation at 884 - 1102 m, Grid Formation at 2049 - 2079 m, Heimdal\r\nand Ty Formations at 2547 m to 2667 m. An RFT run in the Heimdal sand indicated\r\na water gradient, 1.02 g/cm3. The primary target Jurassic sandstones was\r\nencountered at 3070 m in the Hugin and Sleipner Formations. Some shows were\r\nrecorded in the Hugin Formation, but from the logs the formations were all\r\nwater-wet. Possible source rocks were encountered in a comparatively thick and\r\nmarly Blodøks Formation from 2871 m to 2924 m, and in the Late Jurassic Draupne\r\nand Heather Formations from 3004 m to 3070 m. Four conventional cores were cut.\r\nCore 1 was cut from 3061 m to 3062.4 m in the Heather Formation, core 2 was cut\r\nfrom 3082 m to 3100 m in the Hugin Formation, and cores 3 and 4 were cut from\r\n3137 m to 3171 m in the Sleipner Formation. No fluid sample was taken.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe w","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"68","properties":{"OBJECTID":68,"wlbNpdidWellbore":70,"wlbName":"31/2-7","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 31/2-7 was drilled in the\r\nTroll West oil province in the Northern North Sea. The primary\r\nobjective was to appraise the oil accumulation in the area west of well 31/2-4\r\nin the Troll Field. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 31/2-7 was spudded with the semi-submersible\r\ninstallation Borgny Dolphin on 22 April 1982 and drilled to TD at 1660 m in the\r\nLate Jurassic Heather Formation. No significant problems were encountered\r\nduring operations. Tight spots were encountered in the 17 1/2" section. The\r\nwell was drilled with seawater and hi-vis pills down to 455, with\r\nseawater/gel/CMC/Drispac from 455 m to 825 m, with KCl/polymer mud from 825 m\r\nto 1517 m, and with KCl/polymer/gel/lingo mud from 1517 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well penetrated 11 m f Late Jurassic\r\nDraupne shale at 1535 m before entering the Sognefjord Formation reservoir\r\nsands at 1546 m. The Heather Formation was encountered at 1601 m. The\r\nSognefjord Formation was hydrocarbon bearing with a 20.5 m gas column from\r\n1545.5 - 1566 m and a 27.5 m oil column from 1566 to 1593.5 m. The gas\r\nreservoir consisted of alternating micaceous, bioturbated fine to medium\r\ngrained sandstones and cross laminated, massive fine to coarse grained\r\nsandstones. The upper part of the oil reservoir (down to 1586 m) was of the\r\nsame quality as the gas reservoir. Below 1586 m the sandstones were very fine\r\nto medium grained with high mica content. Weak shows (fluorescence and cut)\r\nwere recorded on cores down to 1635 m.\u003c/p\u003e\r\n\r\n\u003cp\u003eSix fibreglass sleeve cores were taken from\r\n1547.0 m to 1635.0 m in the 8 1/2" section. Thus 88 m of core were cut of\r\nwhich 72.25 m (82%) was recovered. In order to verify the higher than expected\r\nGOC several unsuccessful (due to probe plugging) attempts were made to obtain RFT\r\nfluid samples at around 1570 m. Eventually one of the RFT chambers was filled\r\nat 1568 m. After a few more attempts the other chamber was filled at 1566.5 m.\r\nAt surface the contents of both chambers were check","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"69","properties":{"OBJECTID":69,"wlbNpdidWellbore":71,"wlbName":"15/9-14","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 15/9-14 is located ca 7 km south of\r\nthe Sleipner Vest Field in the south Viking Graben of the North Sea. The main\r\nobjectives of the well were sandstones of Late to middle Jurassic age. The\r\nsecondary objective was the Triassic. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 15/9-14 was spudded with the\r\nsemi-submersible installation Deepsea Saga on 1 May 1982 and drilled to TD at 3563\r\nm in Triassic Smith Bank Formation. Operations were conducted without incident\r\nexcept some problems with tight hole and stuck pipe in the 12 1/4"\r\nsection. The well was drilled with spud mud down to 561 m, with seawater/gel/ lignosulphonate\r\nfrom 561 m to 1371 m, with seawater/gypsum/ lignosulphonate from 1371 m to 3016\r\nm, and with lignite/lignosulphonate from 3016 m to TD. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAll objectives proved water bearing\r\naccording to logs and RFT measurements. The RFT data also showed that the\r\npredicted pore pressures had been on the low side. The well was shut in two\r\ntimes due to flow, but there was no pressure build-up. Grains of siltstone and\r\nsandstone in cuttings the interval 1220 to 1260 had weak shows (fluorescence,\r\nno cut). Fluorescence and cut were observed on sandstones from 3220 to 3290 m\r\nin the Vestland Group. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eTwo cores were cut in the Vestland Group.\r\nCore no 1 was cut from 3228 to 3243 m (recovered interval 3228.4 - 3636.6 m\r\ncorrected to loggers depth) and core no 2 was cut from 3267 to 3285.9 (recovered\r\ninterval 3267 m to 3285.9 m) corrected to loggers depth). One RFT run was\r\nperformed in the Middle Jurassic - Triassic Formations. Eleven pre-test samples\r\nwere obtained out of 19 sampling points. No wire line fluid samples were taken.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"70","properties":{"OBJECTID":70,"wlbNpdidWellbore":72,"wlbName":"30/2-1","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 30/2-1 is located roughly mid-way\r\nbetween the Oseberg Field complex and the Kvitebjørn Field in the Northern\r\nNorth Sea. The primary objective of the well was sandstones of Middle Jurassic\r\nage. Secondary objectives were sandstones of Paleocene and Late/Early Triassic\r\nage. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 30/2-1 was spudded with the\r\nsemi-submersible installation Dyvi Delta on 17 May 1982 and drilled to TD at 4243 m, 133 m into the Early Jurassic Statfjord Formation. A total of 125 days\r\nwere spent on the drilling phase, which was 5 days more than prognosed. Twelve\r\ndays were lost due to problems with lost circulation, gas influx, stuck pipe\r\nand a leaking liner overlap in the 8 1/2" hole section. Three and a half\r\ndays were lost to free the 13 3/8" casing when this got stuck at 1998 m. Most\r\nof those days were caught up because total depth was reached 357 m shallower\r\nthan prognosed, and because of successfully turbodrilling with diamond bits in\r\nthe 12 1/4" and 6" hole section. The well was drilled with spud mud\r\ndown to 1035 m, with Gypsum mud from 1035 m to 1860 m, and with\r\nGypsum/Lignosulphonate mud from 1860 m to 2155 m. An oilfaze/pipelax and an\r\nImco spot/pipelax pill was spotted at 1998 m to free the pipe. From 2155 to TD\r\nthe well was drilled with Spersene XP 20 (Lignosulphonate).\u003c/p\u003e\r\n\r\n\u003cp\u003eHydrocarbons were encountered in the\r\nBrent group. The secondary prospects were found to be water wet, although oil shows\r\nwere recorded in dolomite between 1852 m and 1911 m in the Eocene and in a 30\r\ncm thick sandstone bed at 1952 m in the Late Paleocene Balder Formation. Weak\r\nshows were also recorded on sandstones from 4119 m to 4202 m in the Statfjord\r\nFormation.\u003c/p\u003e\r\n\r\n\u003cp\u003eEleven cores were cut with a total\r\nrecovery of 108.8 metres. Two cores were cut from 1952 m to 1969.5 m in the Late\r\nPaleocene Balder Formation, while 9 cores were cut from 3696 m to 3794 m in the\r\n Ness, Etive, and Rannoch Formations of the Brent Group. Fi","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"71","properties":{"OBJECTID":71,"wlbNpdidWellbore":73,"wlbName":"30/6-7","wlbHistory":"\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 30/6-7 is an appraisal well on the\r\nOseberg Field, discovered by well 30/6-1 in 1979.The primary objective was to\r\ntest for hydrocarbon accumulations in the Late Jurassic sandstones of the Brent\r\nformation and the Late and Early Jurassic sandstones of the Dunlin and\r\nStatfjord formations in the Alpha north structure. Secondary objectives were to\r\nestablish the type of communication between the Alpha and Alpha North\r\nstructures and to define the oil/water contact on Alpha North. The well was\r\nplanned to reach total depth at 3225 +- 50 m, 75 m into the Statfjord\r\nFormation.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well is Type well for the Oseberg\r\nFormation and Reference well for the Amundsen, Cook, Drake, Etive, Ness, and\r\nTarbert Formations.\u003cb\u003e \u003c/b\u003e\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 30/6-7 was spudded with the\r\nsemi-submersible installation Nortrym on 20 May 1982 and drilled to TD at 3236\r\nm in Early Jurassic rocks of the Statfjord Formation. The 26" section was\r\ninitiated by a 17 1/2" pilot hole. One small pocket of shallow gas was\r\ndetected at 358 m (5.6% C1). The well was drilled with seawater and hi-vis\r\npills down to 952 m and with KCl/polymer mud from 952 m to 2285 m. At 2285 m\r\nthe 13 3/8" casing got stuck and a pill of EZY spot and diesel was pumped\r\nin the hole, without effect. The drilling fluid used in the 12 1/4"\r\nsection from 2285 m to 2915 m the well was drilled with a Dextrid/KCl mud. From\r\n2915 m to TD the mud was converted to a dispersed system by adding\r\nlignosulfonate.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe Brent Group was encountered at 2631.5\r\nm. The Brent Group was hydrocarbon bearing with a total gross thickness of\r\n154.5 m and a net sand interval of 106.9 m. The net pay was 50.7 m. Sandstone\r\nintervals were also encountered in","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"72","properties":{"OBJECTID":72,"wlbNpdidWellbore":74,"wlbName":"15/9-15","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 15/9-15 was drilled south of the\r\nSleipner Øst Field in the Viking Graben of the North Sea. The objectives were\r\nto test possible hydrocarbon accumulations in Paleocene and Mesozoic sandstones\r\nin the 15/9 My structure. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 15/9-15 was spudded with the\r\nsemi-submersible installation Ross Rig on 28 May 1982 and drilled to TD at 3200\r\nm in the Triassic Skagerrak Formation. During drilling the 12 1/4" section,\r\na significant volume of mud was lost at 2200 m. The thief zone was most\r\nprobably in the Frigg sand. 3 days were spent locating the zone and pumping LCM\r\npills. Otherwise no significant problem was encountered in the operations,\r\nwhich proceeded with little downtime. The well was drilled with spud mud down\r\nto 515 m and with gypsum/lignosulphonate mud from 515 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe Paleocene sandstones were missing in\r\nthis well. The Mesozoic sandstones were encountered at 2806. The upper part\u00A0\r\nconsisted of\u00A0 tight Melke Formation sandstones without shows. From 2821 m (top\r\nSkagerrak Formation) they were gas bearing down to a true gas/water contact at\r\n2923 m. No oil shows were recorded outside of the hydrocarbon-bearing reservoir\r\nin this well.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eFour cores were cut across the reservoir\r\nfrom 2805 m in the Heather Formation to 2878.2 m in the Skagerrak Formation.\r\nThe core-to-log depth shift was 2.8 m for all four cores. RFT fluid samples\r\nwere taken at 282.5 m (gas, condensate and mud filtrate), 2838.5 m (gas,\r\ncondensate and mud filtrate), and at 2907 m (gas, condensate and mud filtrate)\r\nfluid samples were taken.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was permanently abandoned on 1\r\nAugust 1982 as a gas and condensate discovery.\u003c/span","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"73","properties":{"OBJECTID":73,"wlbNpdidWellbore":75,"wlbName":"16/7-3","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eExploration well 16/7-3 is located on the\r\nUtsira High, about ten km east of the Sleipner East field. The objective of the\r\nwell was to test potential Jurassic sands on the large structure in the centre\r\nof the block.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well would also test the Zechstein\r\ncarbonate and Rotliegendes sandstone plays in a small fault block structure.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was spudded with the\r\nsemi-submersible installation Glomar Biscay II and drilled without incident to\r\nTD at 3141 m in the Rotliegendes Group. The well was drilled with seawater gel,\r\nadding lignite from 2150 m.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe Cretaceous sequence consisted of the\r\nLate Cretaceous Tor and Hod chalk formations resting unconformably on a very\r\nthin Late Jurassic Draupne shale. Thirty-seven net m of good quality sand was\r\nencountered in the Jurassic Hugin Formation. The Triassic consisted of red beds\r\nwith no major sand development. The Zechstein contained tight anhydritic\r\ndolomite, some vuggy dolomite, and shales, while the Rotliegendes Group had poor\r\nreservoir quality dolomite cemented sandstones, siltstones and shales. A shows\r\non a core was recorded in the interval 2345 m to 2350.7 m in the upper part of\r\nthe Jurassic Hugin Formation. Otherwise no hydrocarbons were encountered in the\r\nwell. Two cores were taken in the 8 1/2" section, in the interval 2342 m\r\nto 2365.5 m in the Jurassic Hugin Formation. Forty sidewall cores were taken in\r\nthe interval 2296 m to 3130 m. No fluid samples were taken. The well was\r\npermanently abandoned as dry on 28 August 1982.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was performed\u003c/p\u003e\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"74","properties":{"OBJECTID":74,"wlbNpdidWellbore":76,"wlbName":"6407/2-1","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 6407/2-1 was drilled in the\r\nMØre-TrØndelag II area offshore Mid-Norway, approximately 215 km NW of\r\nTrondheim. The overall goal with this early well was to establish the total\r\nstratigraphic column down to Late Triassic. The primary targets were Middle and\r\nthe Early Jurassic Sandstone units. Secondary targets were the sequence below\r\nthe Top Palaeocene reflector, the Early Cretaceous sequence, which could show\r\ndevelopment of sand, and the Triassic sandstones/si1tstones immediately below\r\nthe Åre Formation.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well is Type Well for the Spekk and\r\nRor Formations.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 6407/2-1 was spudded with the\r\nsemi-submersible installation West Venture on 3 June 1982 and drilled to TD at\r\n3870 m, 40 into the Late Triassic Red Beds. Operations went without significant\r\nproblems. The well was drilled with spud mud down to 409 m. The 26"\r\nsection was first drilled as a 14 3/3" pilot hole from 409 m to 1013 m\r\nusing gel/gypsum mud. At this point 30 bbl of diesel was added to reduce mud\r\nweight. The hole section was then opened up with a 26" underreamer using\r\ngel/gypsum mud with further diesel addition. The 17 1/2 section was drilled\r\nwith polymer/gypsum/lignosulphonate from 1013 m to 2215 m, and the remaining\r\nwell was drilled with a lignite/lignosulphonate mud down to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well proved mainly claystones down to\r\nMiddle and Early Jurassic Sandstones. The Tertiary with a total thickness of\r\n1848.5 m, rested unconformably on the Late Cretaceous where the topmost\r\nMaastrichtian was missing. Otherwise the Cretaceous section was nearly\r\ncomplete, and relatively thick (ca 700 m) compared to other wells in the area.\r\nHigh gas readings were experienced in the upper part of the Cretaceous\r\n(Santonian - Campanian) with weak oil shows on cuttings and two SWCs. A study\r\nof wire line logs, sidewall cores and hole response indicated that the gas was\r\noverpressured, and trapped in a non-reservoir lithology. The bas","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"75","properties":{"OBJECTID":75,"wlbNpdidWellbore":77,"wlbName":"30/6-8","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 30/6-8 was drilled on the Epsilon\r\nstructure between the Oseberg and Brage discoveries. At the well location\r\nseismic mapping indicated structural closure at Brent Group level and below. The\r\nprimary objectives were to find hydrocarbon accumulations within the Brent\r\nGroup and the overlying clastic wedge of Bathonian-Callovian age. Other\r\nJurassic sandstones were also considered as prospective targets. The well was\r\nplanned to reach ca 3500 m total depth, 75m into the Statfjord Group.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 30/6-8 was spudded with the\r\nsemi-submersible installation Treasure Seeker on 15 June 1982 and drilled to TD\r\nat 3600 m in the Early Jurassic Statfjord Formation. A 17 1/2" pilot hole\r\nwas drilled from 232 m to 950 m. No shallow gas was reported. No serious\r\nproblems occurred while drilling. The well was drilled with seawater and hi-vis\r\npills down to 232 m, with seawater/hi-vis pills and Drispac from 232 m to 955\r\nm, and with KCl/polymer mud from 955 m to TD. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo hydrocarbon bearing sandstone\r\nintervals were encountered in this well. The only hydrocarbon indications were fluorescence\r\nand cut fluorescence in sandstone cuttings at 3560 to 3563 m in the Statfjord\r\nGroup and trace fluorescence, no cut, in sidewall cores at 3147 and 3154 m in\r\nthe Etive Formation. The well penetrated an Intra Heather Formation Sandstone\r\ninterval (2445.5 - 2523.5 m) with 10.6 m net with average porosity of 15.7 %. A\r\nCallovian wedge (2712.5 - 3024 m) was encountered by the well, but no clastic\r\nsediments with reservoir properties were found within the wedge. A total of 147\r\nm of Brent Group (3024 - 3171 m) sediments were encountered. Net sand was 45.9 m\r\nwith an average porosity of 16.1 %. Net sand within the Cook Formation (3349.5 -\r\n3404.","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"76","properties":{"OBJECTID":76,"wlbNpdidWellbore":78,"wlbName":"31/2-8","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 31/2-8 was drilled in the northern\r\npart of block 31/2, some 3 km NW of the Troll Field boundary, to test a\r\ndownthrown Jurassic fault-block outside the Troll Field. The primary objective\r\nwas the Late Jurassic, shallow marine sands of the Viking Group, especially the\r\nSognefjord Formation. The Early Jurassic was secondary objective and would be\r\nevaluated by drilling into Triassic sediments. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 31/2-8 was spudded with the\r\nsemi-submersible installation Borgny Dolphin on 16 June 1982 and drilled to TD\r\nat 3375 m in the Triassic Hegre Group. A gas zone (confirmed by logs) between\r\n510 - 530 m did not cause any problems during drilling of the 14 3/4"\r\npilot hole. Maximum gas reading through this zone was 10 %. The hole was\r\ndrilled to 840 m and under-reamed to 26" without incident. The 17\r\n1/2" section was drilled first by an 8 1/2" pilot hole down to 1063 m\r\nto provide better control when drilling through a potential gas charged fault\r\nplane. No indications of gas were seen. 3 cores were taken in the 12 1/4"\r\nsection. Two washouts occurred when drilling the 8 1/2" hole below 3317 m.\r\nThe well was drilled with seawater gel down to 840 m, with KCl/polymer from 840\r\nm to 1745 m, with seawater and Drispac from 1745 m to 2743 m and wit\r\nDrispac/lignosulphonate from 2743 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eOnly 13 m of Shetland Group chalk was found on top of the Kimmerian unconformity at 1821 m. The Viking\r\nGroup contained a 15.5 m thick Draupne shale on top of a 680 m thick sequence\r\nof sandstone units interbedded in the Heather Formation. The Middle to Early\r\nJurassic was also well developed. Shows occurred sporadically in limestones,\r\nsiltstone, and claystones through the Early Tertiary and Late Cretaceous. When\r\nentering into the Late Jurassic reservoir sands at 1836.5 m (Sognefjord\r\nFormation) ditch gas readings went up to more than 4% from a background lower\r\nthan 1%, but without oil indications in the upp","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"77","properties":{"OBJECTID":77,"wlbNpdidWellbore":79,"wlbName":"15/9-16","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 15/9-16 was drilled on the Sleipner\r\nØst discovery in the southern Viking Graben of the North Sea. The primary\r\nobjective was to delineate the hydrocarbon accumulations in the Heimdal\r\nFormation on the gamma structure. Sandstones of Jurassic/Triassic age were\r\nsecondary objectives. It was the fourth well drilled on this structure.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 15/9-16 was spudded with\r\nthe semi-submersible installation Deepsea Saga on 28 June 1982 and drilled to\r\nTD at 3120 m, 52 m into the Permian Rotliegendes Group. The 9 5/8" casing\r\nhad a leak at 522 m. It was squeezed twice with cement before it held a reduced\r\npressure. Otherwise, no significant problem was encountered in the operations.\r\nThe well was drilled with gel/seawater spud mud down to 515 m, with\r\ngypsum/lignosulphonate mud from 515 m to 2652 m, and with a\r\nseawater/lignite/lignosulphonate mud from 2652 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eTop Heimdal was encountered at 2378 m. It\r\ncontained gas and condensate, but was thinner than expected. Pressure data\r\nindicated a gas/water contact at 2434 m. The logs showed a sharp increase in\r\nwater saturation at 2428 m. Weak oil shows were recorded on cores between 2418\r\nm and 2427.5 m. The prognosed sandstones of Jurassic/Triassic age were not\r\npresent at this location. Fair shows were recorded on cuttings in evaporites at\r\n3014 m, at top Zechstein Group level. No shows were recorded on sidewall cores\r\nfrom the same level.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eA total of 113.5 m of core (98% recovery)\r\nwas cut in seven cores in the interval 2382 to 2498 m. cores were cut and no\r\nwire line logs were run in the well. An RFT fluid sample was taken at 2380 m\r\n(good recovery), while attempts to sample at 2411m, 2413 m, and 2426 m gave\r\npoor ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"78","properties":{"OBJECTID":78,"wlbNpdidWellbore":80,"wlbName":"2/2-2","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 2/2-2 was located near the crest of\r\nan elongated salt-induced domal structure in the NW corner of the block. The\r\nmain target was the Late Jurassic Ula Formation shallow marine sandstone.\r\nSandstones of Middle Jurassic and Late Triassic age were possible secondary\r\ntargets, having the same structural definition as the Ula sand. Secondary\r\nobjectives were further represented by the Late Cretaceous chalk and a\r\nsandstone of Oligocene age. \u003c/p\u003e\r\n\r\n\u003cp\u003eAccording to the license agreement, the\r\nwell should be drilled into the Triassic, salt or a maximum depth of 5000 m\r\nwhatever came first. The well reached a TD of 3124 m in Permian anhydrites thus\r\nfulfilling the work commitment.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 2/2-2 was spudded with the\r\nsemi-submersible installation Dyvi Alpha on 4 April 1992 and drilled to TD at\r\n3124 m in the Late Permian Zechstein Group. When drilling the 36" hole,\r\nthe pipe stuck. After the pipe was worked free, the drilling continued. The\r\nwell took a kick at 2425 m. The well was drilled with seawater and bentonite\r\ndown to 715 m, with polymer/gypsum/"SST 202" mud from 715 m to 1965\r\nm, and with lignite mud from 1965 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well penetrated porous layers in the\r\nOligocene, the Cretaceous and the Jurassic. A full suit of logs was run in\r\nthese sections. In the interval 1978-2057 m of the Oligocene, a bioturbated and\r\ncross-laminated very fine sandstone, interbedded with siltstone and shale was\r\nfound (the Vade Formation). The upper part of the sand was found gas bearing\r\nfrom 1978 m down to a GWC at 2002 m. Net pay thickness was 14 metres. A\r\nsegregated RFT gas sample was taken at 1996.4 m. The sand has a porosity of 24%\r\nwith a shale content of 25%. A water saturation of 40% was estimated. The core\r\nanalysis gave an average porosity of 27 %, but this is probably too high\r\nbecause the core-plugs were drilled mainly in clean silt/sandstone intervals.\r\nBelow the gas water contact, a net sand thickness of 13 m w","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"79","properties":{"OBJECTID":79,"wlbNpdidWellbore":81,"wlbName":"6507/10-1","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eExploration well 6507/10-1 was the sixth\r\nwell drilled on the Mid Norway continental shelf area. It is located in between\r\nlater discoveries such as SmØrbukk, Heidrun, and Midgard. The main targets of\r\nthe well were sandstones of middle to Late Jurassic age. Secondary targets were\r\nsandstones of Early Tertiary, Early Jurassic and Triassic age. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe well is Reference Well for the Ror\r\nFormation.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 6507/10-1 was spudded with\r\nthe semi-submersible installation Sedco 707 on 10 July 1982 and drilled to TD\r\nat 3693 m in the Åre Formation. Tight hole was experienced at the bottom of the\r\n13 3/8" section. While drilling the 12 1/4" section the drill string\r\nstuck. After several attempts to free the string, the well was sidetracked. The\r\nsidetrack was drilled to 2007 m where the string again got stuck. The well was\r\nthen sidetracked again to 2220 m at which point the string got stuck again.\r\nThis time the string was jarred free and the 12 1/4" hole was finally drilled\r\nto 2780 m. Problems with the BOP and wellhead delayed operations in the 8\r\n1/2" section. The well was drilled with spud mud down to 440 m, with a sea\r\nwater/clay built native mud from 440 m to 913 m, and with CMC/gypsum mud from\r\n1971 m to 2149 m. From 2149 m to 2780 m the mud was gradually broken over to a\r\nlignosulphonate (Spersene) mud, and from 2780 m to TD a Spersene/XP 20 mud was\r\nused.\u003c/p\u003e\r\n\r\n\u003cp\u003eSandstones were found in the Middle and\r\nEarly Jurassic. The Early Tertiary sandstones were not present. The Triassic\r\nsandstone horizon was not penetrated. An 11% methane gas peak was recorded from\r\na Miocene sandstone at 590 m but no fluorescence was noted. Sandstone in the\r\ninterval 1790-1805 m produced a slow crush cut fluorescence as did the Late\r\nJurassic mudstone between 2779 m and 2828 m in the Spekk Formation. These were\r\nthe only hydrocarbon indications recorded in the well. Logs and RFT pressure\r\ngradients proved all potential rese","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"80","properties":{"OBJECTID":80,"wlbNpdidWellbore":82,"wlbName":"7120/9-1","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 7120/9-1 was drilled in the Hammerfest Basin. The primary objective of the well was to test sandstone reservoirs of\r\nEarly to Middle Jurassic age at a location very close to the highest position\r\nof the prospective structure.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was to be drilled into sediments\r\nof Triassic age to a prognosed depth of 2180 m +100/-130.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eExploration well 7120/9-1 was spudded\r\nwith the semi-submersible installation Treasure Scout on 25July 1982 and\r\ndrilled to TD at 2300 m in the Triassic Snadd Formation. The 36" section\r\nwas drilled with a 17 1/2" bit followed by a 36" hole opener. Low\r\npenetration rates were encountered due to the over-compacted nature of the clay\r\nformation together with the presence of numerous erratic glacial boulders. The\r\nhole had to be reamed 3 times before the 30" casing was set. After that\r\ndrilling proceeded without major problems. The 36" section was drilled\r\nwith mud left from the previous well (7117/9-1). The 26" section down to\r\n760 m was drilled with seawater and prehydrated bentonite. From 760 m to 1651 m\r\nthe well was drilled with gypsum/"Milpolymer 302" mud, and from 1651\r\nm to TD the well was drilled with "Milpolymer 302".\u003c/p\u003e\r\n\r\n\u003cp\u003eThe main reservoir was found hydrocarbon\r\nbearing from 1840.5 m (Top Stø Formation) down to the gas/water contact at 1904\r\nm, eight meter into the Nordmela Formation. This interval consists of fine to\r\nmedium, occasionally coarse sandstones with a few thin claystone stringers. RFT\r\npressure recordings and sampling were performed over the interval. This gave a\r\nclear gas gradient of 0.084 psi/ft down to 1904 m with an underlying water\r\ngradient of 0.48 psi/ft. Weak to good shows were reported in sandstones in the\r\ninterval from 1904 m in the lower part of the Early Jurassic and into the Triassic\r\nat TD. The water saturation in this interval ranged from 50-100% and based on\r\nlog interpretation the hydrocarbons were assume","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"81","properties":{"OBJECTID":81,"wlbNpdidWellbore":83,"wlbName":"30/6-9","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 30/6-9 was drilled on the Gamma\r\nstructure on the Oseberg Field in the northern North Sea. The Gamma structure\r\nlies on the west side of the Alpha structure and is separated from it by a\r\nlarge northwest-southeast fault. The primary objectives of well 30/6-9 were to\r\ntest hydrocarbon accumulations in the Brent Group and find additional\r\nhydrocarbon accumulations within the Early Jurassic. This was the first well\r\nlocated on the Gamma structure. Planned depth for the well was ca 3360 m or 75\r\nm into the Triassic Lunde Formation. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 30/6-9 was spudded with the\r\nsemi-submersible installation Nortrym on 28 August 1982 and drilled to TD at 3476\r\nm in the Late Triassic Lunde Formation. No significant problems occurred while\r\ndrilling the well. The well was drilled with seawater, bentonite and hi-vis\r\npills down to 975 m, with KCl/polymer mud from 975 m to 2750 m, and with\r\nlignite/lignosulphonate/freshwater mud from 2750 m to TD\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWeak to strong shows were reported mainly\r\nin soft limestone stringers in the lowermost part of the Lista Formation in the\r\nLate Paleocene, in the Danian, and through the Maastrichtian. Further shows above\r\nthe Brent Group were reported in cuttings in limestones from 2410 to 2422.5 m,\r\njust above the Late Jurassic unconformity. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe main target, Brent Group was penetrated\r\nfrom 2458 to 2620 m. It was hydrocarbon bearing over the entire interval with\r\nthe gas/oil contact calculated from FMT pressure recordings at ca 2520 m. This\r\nis the same, as the GOC on the Alpha structure. No oil/water contact was\r\nencountered. The net pay in the Brent Group is calculated to be 98 m giving a\r\nnet/gross ratio of 0.60. The average porosity is 22.7% with ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"82","properties":{"OBJECTID":82,"wlbNpdidWellbore":84,"wlbName":"16/1-3","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 16/1-3 is located on the Gudrun\r\nTerrace west of the Utsira High. The main objective of the well was to evaluate\r\nthe hydrocarbon potential of Jurassic sand reservoirs. Eocene and Paleocene\r\nsands were secondary objectives. 16/1-3 was drilled on the flank of a\r\nseismically defined structure. The prime crestal location could not be tested\r\ndue to the presence of a telephone cable on the sea floor. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 16/1-3 was spudded with the\r\nsemi-submersible installation Glomar Biscay II on 29 July 1982 and drilled to\r\nTD at 3498 m in granite basement. After losing returns while drilling at 210 m,\r\nthe 30" casing was re-cemented. Shallow gas was encountered between 400\r\nand 444 meters. Tight hole, swabbing on trips and reaming were recurrent\r\nproblems in the 12 1/4" hole due mainly to swelling of claystone and\r\nsiltstone. Mud was lost when drilling through a flint layer at 2638 m. The well\r\nwas drilled with seawater and bentonite down to 702 m, with a\r\nlignosulphonate/CMC mud from 702 m to 2282 m, and with lignosulphonate/lignite\r\nmud from 2282 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eMechanical log analysis over the Jurassic\r\ninterval indicated the presence of about 60 meters of gross sand. Two thin\r\nzones of approximately 4 meters each in thickness were interpreted to be\r\nhydrocarbon bearing. The remaining sands were judged to be water bearing or\r\nnon-reservoir. No reservoir was believed to be present in the Triassic sand,\r\nsiltstones and shales. Minor shows, consisting of stain, fluorescence and/or\r\nmud gas manifestations were recorded in the Pliocene-Eocene, Miocene and\r\nPaleocene sections. In addition, oily mud was recovered in one of the MFT\r\nsamples from the Jurassic Sleipner Formation. The Zechstein formation contained\r\ngenerally tight anhydritic dolomites at the top. A porous but interpreted water\r\nbearing limestone section was found in the middle portion of the Zechstein\r\nGroup. Below the limestone a 36 m thick sandstone sequence was encounte","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"83","properties":{"OBJECTID":83,"wlbNpdidWellbore":85,"wlbName":"7120/7-1","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 7120/7-1 is located on the\r\nRingvassøy-Loppa Fault Complex, in the Snøhvit Field area. It was drilled to\r\ntest possible hydrocarbon accumulations in sandstones of Middle to Early\r\nJurassic age in the Alpha structure. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 7120/7-1 was spudded with the\r\nsemi-submersible installation Neptuno Nordraug on 31 July 1982 and drilled to\r\nTD at 2839 m in Late Triassic sediments of the Tubåen Formation. The 26"\r\nsection was first pilot-drilled with a 12 1/4" bit to 752 m. Logging of\r\nthe pilot hole confirmed a gas bearing sandstone from 375 to 392 m and it was\r\ndecided to set the 20" casing above the sand and then set the 13-3/8"\r\ncasing around the planned 20" casing shoe depth. Some gas problems delayed\r\nplug-back operations, but otherwise operations went smoothly, and the well was\r\nabandoned 4 days ahead of schedule. The well was drilled with seawater/gel down\r\nto 865 m, with gypsum/polymer mud from 865 m to 1917 m, and with\r\ngel/lignosulphonate mud from 1917 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eHydrocarbon accumulations were discovered\r\nin the target sandstone sequence (Stø Formation) from 2408 m to 2473 m. The\r\nsandstones showed good to excellent reservoir properties. Weak shows were\r\nrecorded in claystones in the interval from 1941 m to 2172 m and sporadically\r\nin the lower part of the Hekkingen Formation. Shows were recorded in sandstones\r\nthroughout the reservoir and down to 2620 m. Sporadic shows were recorded from\r\nthis depth down to TD. Organic geochemical analyses show an excellent source\r\nrock with high TOC (3 % to almost 9 % ) with type II/ III kerogen in the lower\r\npart of the Hekkingen Formation, from 2274 m to its base. Source potential for\r\ngas and condensate was seen in the Cretaceous Kolje Formation from 1995 m to\r\n2205 m and in the Early Jurassic Tubåen Formation from 2651 m to 2799 m. The\r\nwell is immature down to ca 2000 m (%Ro ca 0.5) and at peak oil window maturity\r\nat TD (%Ro ca 0.8). In contrast to the w","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"84","properties":{"OBJECTID":84,"wlbNpdidWellbore":86,"wlbName":"7/11-6","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 7/11-6 is located approximately half\r\nway between the Mime and the Ula Fields in the North Sea. The primary objective\r\nof well 7/11-6 was to test Late Jurassic sandstones. The secondary objective of\r\nthe well was to test sandstones of Triassic age. The well was planned to reach\r\ntotal depth at 4400 +/- 200 m, approximately 100 m in to the Triassic.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 7/11-6 was spudded with the\r\nsemi-submersible installation Treasure Seeker on 9 August 1982 and drilled to\r\nTD at 4500 m in the Triassic Smith Bank Formation. The well was drilled without\r\nincident except some problems with gumbo in the 17 1/2" section. The well\r\nwas drilled with seawater and high viscosity pills of pre-hydrated\r\nbentonite/lime mud down to 670 m, with KCl/Drispac mud from 670 m to 2060 m,\r\nwith KCl/Drispac mud converting to gel/lignosulphonate mud in the 2060 m to\r\n3970 m section, and with a lignosulphonate mud from 3970 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well encountered a Late Jurassic Ula\r\nFormation gross sand interval of 47 m between 4098 and 4145 m. Based on wire\r\nline log evaluation net sand was 21.25 m with an average porosity of 15.8%. The\r\nUla Formation rests unconformable on the Triassic Smith Bank Formation, which\r\nconsists of interbedded sandstones and shales with local siltstones and rare\r\nstringers of limestone. Both the Jurassic and Triassic sandstones proved water\r\nbearing, but with residual hydrocarbons in the Ula Formation, based on logs.\r\nShows were reported in the interval 4007.5 m to 4038 m in the Late Jurassic hot\r\nshale unit, in the Ula Formation, and some meters into the Triassic.\u003c/p\u003e\r\n\r\n\u003cp\u003eFour cores were taken in the 8 3/8"\r\nsection. Cores 1 to 3 were cut mainly in the Ula Formation. The lower part of\r\ncore 3 and all of core 4 were cut in the Triassic Smith Bank Formation.\r\nThirteen RFT pressure tests were attempted in the well over the interval of\r\n4106 to 4204.5 m. From the pressure tests a water gradient of 0.44 psi/ft\r\n(1.014 gm/c","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"85","properties":{"OBJECTID":85,"wlbNpdidWellbore":87,"wlbName":"1/3-3","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 1/3-3 is located on the Cod Terrace\r\nin the North Sea. It was drilled to evaluate the hydrocarbon potential of both\r\nthe Late Jurassic and the Triassic sandstone formations. Main target was the Late\r\nJurassic Ula Formation found oil bearing in the Ula field, 17 km to the NW, and\r\nin the well 2/1-3. Secondary target was the Triassic sandstone found oil\r\nbearing in the well 7/12-6 in the Ula field. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 1/3-3 was spudded with the\r\nsemi-submersible installation Borgsten Dolphin on 22 August 1982 and drilled to\r\nTD at 4876 m logger's depth (4867 m driller's depth). The well was drilled\r\nusing water based mud. Two drilling breaks occurred, one at 4127 m and one at\r\n4180 m.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThin layers of sandstone were found in\r\nthe Palaeocene. The Chalk Group was 686 m thick. Less than 10 m of sandstones\r\nscattered in several thin layers were encountered and partially cored in the\r\nFarsund Formation, they were found tight. The Late Jurassic Ula Sandstones,\r\nwhich were the main objective, were found at 4178 m and they were oil bearing\r\ndown to an OWC at 4221 m, but with only ca 5 m pay zone. The upper half with\r\nthe best reservoir qualities was cored (cores 2 to 6). The coaly Bryne\r\nFormation is assigned at 4527 m, top Triassic Smith Bank Formation at 4620 m,\r\nand the Zechstein evaporitic rocks, anhydrite (26 m) and halite was penetrated\r\nfrom 4820 m to TD. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eResidual hydrocarbon saturation based on\r\nelectric logs were seen in the Paleocene at 3068 to 3093 m and in top Triassic\r\nat 4622 to 4637 m. Shows were reported as follows: Direct yellow fluorescence\r\non cuttings at 2955 m; Weak direct fluorescence and poor streaming yellow cut fluorescence\r\non cuttings at 3075 - 3145 m; Yello","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"86","properties":{"OBJECTID":86,"wlbNpdidWellbore":88,"wlbName":"31/2-9","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 31/2-9 was drilled northeast\r\nof the well 31/2-7 in the Troll West oil province in the Northern North Sea. The\r\nmain objectives were to establish the extent of a previously proven thick oil\r\ncolumn province in the Troll Field and to complete the well near the OWC in\r\norder to follow the development of water coning. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 31/2-9 was spudded with the semi-submersible\r\ninstallation Borgny Dolphin on 29 August 1982 and drilled to TD at 1770 m in the Late Jurassic Fensfjord Formation. Some problems\r\nwere encountered with the well head after running the 20" casing (2.5 days\r\nlost), and with the BOP after running the 13 3/8" casing (3.5 days lost). The\r\nwell was drilled with spud mud down to 460 m, with seawater and gel from 460 m\r\nto 816 m, with KCl/polymer mud from 816 m to 1509 m, and with seawater/Drispac\r\nmud from 1509 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 31/2-9 encountered a hydrocarbon bearing column of\r\n34.5 m in the Late Jurassic Sognefjord Formation. The reservoir was gas bearing\r\nfrom 1549 -1570 m (21 m gas column) and oil bearing down to 1583.5 m (13.5 m\r\noil column). This was a thinner oil column than expected. The gas reservoir\r\nconsisted of very fine to medium grained bioturbated sandstones with a high\r\nmica content. The sandstones were very silty and well sorted. Around 1570 m a\r\nchange in lithology to medium/ coarse grained sandstones with low mica content\r\nand less bioturbation was seen. In the lower part of the oil reservoir the mica\r\ncontent was slightly more than in the upper part and the sandstones were siltier.\r\nBelow the OWC shows (moderate to very weak direct fluorescence) were observed\r\non cores throughout the cored section down to 1628 m.\u003c/p\u003e\r\n\r\n\u003cp\u003eFive fiberglass sleeved cores were taken in the 12\r\n1/4" section from 1554 to 1628 m. Four RFT runs were made and 5 samples\r\nwere obtained: at 1573 m (29 deg API oil), 1571 m (oil), 1565 m (gas), and two\r\nsamples at 1575 m (oil)\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently ab","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"87","properties":{"OBJECTID":87,"wlbNpdidWellbore":89,"wlbName":"8/3-2","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 8/3-2 is located in the Egersund\r\nBasin in the North Sea. The primary objective of 8/3-2 was to test possible\r\nhydrocarbon accumulations in sandstones of Middle Jurassic and Triassic\r\nsandstones. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 8/3-2 was spudded with the\r\nSemi-submersible installation West Vanguard on 4 October 1982 and drilled to TD\r\nat 2657 m in the Triassic Skagerrak Formation. This was the first well drilled\r\nby West Vanguard. Drilling of the 36" and 26" sections were without\r\nincident, however the BOP stack required extensive repair and eight days were\r\nspent waiting on parts and repairs. Gumbo caused some delay in the 17 1/2"\r\nsection. The well was drilled with spud mud down to 501 m, with polymer/gypsum\r\nmud from 501 m to 1150 m, and with gel/lignosulphonate mud from 1150 m to TD.\r\nThe well encountered Middle Jurassic (Bryne Formation) sandstones with good\r\nreservoir properties from 2375 m to 2417 m. \u003c/p\u003e\r\n\r\n\u003cp\u003eThis was thinner than expected. A thin\r\nsandstone sequence was encountered from 2465 m to 2474 m in the underlying\r\nSkagerrak Formation. Some shows were recorded in shales from the interval 2088\r\nm to 2355. The lower part of the Tau Formation is a "hot shale"\r\ncharacterized by very high gamma ray readings. No shows were seen in the porous\r\nsections and electrical logs and RFT pressure gradients confirmed water wet\r\nreservoirs. Organic geochemical analyses proved excellent source rock potential\r\nin the Late Jurassic shales, with TOC in the range 2 % to 7 % and hydrogen\r\nindex in the range 250 to 600 mg HC/g TOC. Best potential is seen in the Tau\r\nFormation. The well is immature for oil and gas generation with %Ro = 0.45 -\r\n0.5 towards TD. The analyses indicate shows of wet gas in the Bryne Formation\r\nsandstones, but otherwise confirm the shows recorded during drilling. Two\r\nconventional cores were taken in the interval 2384 m to2397.3 m in the Bryne\r\nFormation. No fluid samples were taken.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well w","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"88","properties":{"OBJECTID":88,"wlbNpdidWellbore":90,"wlbName":"31/2-10","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 31/2-10 was drilled as an appraisal\r\nwell in the Troll West oil province in the Northern North Sea. The main\r\nobjectives were to define the top and intra reservoir markers in this area of\r\nthe Troll West, establish the extent of the 27.5 m oil column in the area in\r\nwhich the GOC is at 1541 m sub-sea (1567 m RKB), and to determine the reserves\r\npotential in the structurally low area east-north of well 31/2-5 and south east\r\nof 31/2-7. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThe site survey revealed, typical for the\r\narea, numerous pockmarks. These had a fairly random distribution of 15 to 20\r\nper km2. Although the size of individual pockmarks varied, average sizes were\r\nbetween 30 and 40 m wide at the rim, and 3 to 4 m deep at the centre. At the\r\nlocation itself no pockmark was seen. \u003c/p\u003e\r\n\r\n\u003cp\u003eWell 31/2-10 was spudded with the semi-submersible\r\ninstallation Borgny Dolphin on 2 October 1982 and drilled to TD at 1833 m, 40 m\r\ninto in the Early Jurassic Fensfjord Formation. After drilling the 36"\r\nsection, a 14 3/4" pilot hole was drilled to 810 m. The hole was then\r\nlogged without indication of shallow gas before opening up to 26". One and\r\na half days were lost during coring due to bad weather. The well was drilled\r\nwith spud mud down to 472 m, with gel/seawater from 472 m to 810 m, with KCl/polymer\r\nmud from 810 m to 1530 m, and with seawater/Drispac from 130 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eTop Jurassic was encountered with a 35 m\r\nthick Draupne shale. The Sognefjord Formation sands were encountered at 1600 m,\r\nbelow the prognosed OWC. The Heather Formation came in at 1733 m, and the\r\nFensfjord Formation at 1793 m. From top Sognefjord Formation to 1647 m bleeding\r\noil and oil stained grains were noted on the cores. However the petrophysical\r\ninterpretation concluded the sands to be water bearing. \u003c/p\u003e\r\n\r\n\u003cp\u003eTen cores were taken in the interval 1575\r\nm to 1741.5 m and 127.98 m (77%) was recovered. All cores were taken in\r\nfibreglass sleeves to achieve better recovery ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"89","properties":{"OBJECTID":89,"wlbNpdidWellbore":91,"wlbName":"16/7-4","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 16/7-4 is located ca 10 km southeast\r\nof the Sleipner Øst Field and 6 km east of the 15/9-15 gas discovery in the North Sea. The objective of the well was to test the presence of a structural trap in\r\nJurassic/Triassic sandstones on the A-North Prospect in the southwest corner of\r\nBlock 16/7. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 16/7-4 was spudded with the\r\nsemi-submersible installation Glomar Biscay II on 15 October 1982 and drilled\r\nto TD at 2781 m in the Triassic Group. The well was drilled with seawater\r\nand gel all through.\u003c/p\u003e\r\n\r\n\u003cp\u003eOnly 1.5 m Jurassic sediments (Draupne\r\nFormation) were present in well position. The Triassic Group sandstone was\r\nencountered at 2521.5 m and held a 117.8 m gas/condensate column from top and\r\ndown to 2639.3 m (-2314.3 m subsea). The gas-bearing sandstones were found\r\ninterbedded with a few thin shales. The reservoir quality was best near the top\r\nof the sand, becoming gradually poorer downwards. The net gas sand was 85.4 m\r\nwith 23% porosity and 36% average water saturation. No shows were reported from\r\nabove or below the hydrocarbon-bearing interval in the well.\u003c/p\u003e\r\n\r\n\u003cp\u003eSix conventional cores were cut from 2568\r\nto 2681.5 m to in the Jurassic - Triassic interval. One Multi Formation Tester\r\n(MFT) fluid sample was taken at 2638.5 m. It recovered 1.2 litres of 57 deg API\r\ncondensate, 1.3 Sm3 gas and 2 litres of water.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 6\r\nDecember 1982 as a gas/condensate discovery.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eTwo drill stem tests were performed in\r\nthe Triassic Group. \u003c/p\u003e\r\n\r\n\u003cp\u003eDST 1 at 2590.5 - 2597 m flowed 199 Sm3\r\ncondensate and 385110 Sm3 gas /day through a 42/64" choke. The\r\ngas/condensate ratio was 1938 Sm3/Sm3, the oil gravity was 58 deg API, and the\r\ngas gravity was 0.791 (air = 1).\u003c/p\u003e\r\n\r\n\u003cp\u003eDST 2 at 2525 - 2535 m flowed 253 Sm3\r\ncondensate and 472890 Sm3 gas /day through a 42/64" choke. The\r\ngas/condensate ratio was 1871 Sm3/Sm3, the oil gravity was 59 deg API, and","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"90","properties":{"OBJECTID":90,"wlbNpdidWellbore":92,"wlbName":"30/6-10","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 30/6-10 was drilled to appraise the\r\nhydrocarbon potential in the Alfa structure on the Oseberg Field in the North\r\nSea. The main objective was to define the gas/oil contact and to obtain cores\r\nfrom this zone.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 30/6-10 was spudded with\r\nthe semi-submersible installation Treasure Scout on 4 October 1982 and drilled\r\nto TD at 2656 m in the Early Jurassic Drake Formation. Some problems were\r\nencountered while running both 20" and 13 3/8" casing. The drill\r\nstring got stuck at 1992 m and leakages in the BOP stack after installing the\r\n13 3/8" casing also occurred. The well was drilled with seawater and\r\nhi-vis pills down to 970 m and with KCl/polymer mud from 970 m to TD. At 1992 m\r\n15 m3 diesel and 15.9 m3 Imco spot was pumped to free the pipe. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eFirst oil show in the well was recorded\r\nat 1980 m in limestone stringers at top Balder Formation level. Poor oil shows\r\nwere recorded in the intervals 2030 to 2100 m and 2215 m to 2253 m. Good oil\r\nshows were recorded on cuttings from marls and limestones in the Shetland Group\r\nfrom 2253 m to 2380 m, then again poor shows were recorded down to top of the\r\nBrent Group at 2457 m. The well encountered oil and gas in Middle Jurassic\r\nBrent sandstones. The Brent Group was found hydrocarbon bearing over the entire\r\n118 m interval. Net pay was 37.3 m with 23.3 % average porosity and 23.9%\r\naverage water saturation. The gas/oil contact was found from RFT pressure gradients\r\nto be at 2520 m in the Ness Formation, but no oil/water contact was\r\nencountered. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eA total of eleven conventional cores were\r\ncut from the top of the Ness Formation and down into the Dunlin Group shales. Driller\r\ndepths through the cored","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"91","properties":{"OBJECTID":91,"wlbNpdidWellbore":93,"wlbName":"31/2-13 S","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 31/2-13 S was drilled as an appraisal in the Troll\r\nWest oil province in the Northern North Sea. The main\r\nobjectives of were to investigate the reservoir properties and accumulation\r\nconditions between the wells 31/2-5 and 31/2-11. Water and/or gas -coning tests\r\nwere to be conducted. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eAppraisal well 31/2-13 S was spudded with\r\nthe semi-submersible installation Borgny Dolphin on 2 January 1984 and drilled\r\nto TD at 2010 m in the Middle Jurassic Fensfjord Formation. Due to bad weather\r\nthe string parted and was observed lying across the temporary guide base when\r\nthe well was spudded. The fish was recovered. Straight hole was drilled down to\r\n500 m where the hole was kicked off with an angle of 1 1/2 degree. Some\r\nproblems due to tight hole occurred in the 17 1/2" hole. Mud losses to the\r\nformation occurred at 1531 and 1700 m, 100 bbls at each depth. A drill break\r\noccurred at 1744 m in the 12 1/4" hole section. The well was drilled with\r\nseawater and viscous pills down to 473 m, with Gelled mud from 473 m from 473 m\r\nto 750 m, with seawater from 750 m to 825 m, and with oil based mud from 825 m\r\nto TD. The Oil based mud used was termed "Fazekleen, low toxicity invert\r\noil emulsion mud, based on Shell Sol D70 oil"\u003c/p\u003e\r\n\r\n\u003cp\u003eTop reservoir (top Sognefjord Formation) was\r\npenetrated at 1732 m (1526.5 m TVD), top Heather Formation at 1855 m (1613 m\r\nTVD), and top Fensford Formation sandstone at 1934 m (1671 m TVD). Oil and gas were\r\nencountered in the Sognefjord Formation. The GOC was at 1790 m (1567 m TVD) and\r\nthe FWL was estimated at 1828.5 m (1594 m TVD). Strong to moderate fluorescence\r\nwas observed on the cores down to 1844 m (1606 m TVD), but heavy contamination\r\nfrom the oil-based mud made shows detection somewhat uncertain. The upper half\r\nof the oil bearing formation consisted of generally clean sandstones. Below\r\n1555 m TVD the sands were micaceous. Tight calcareous streaks occurred over the\r\nwhole sectio","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"92","properties":{"OBJECTID":92,"wlbNpdidWellbore":94,"wlbName":"15/12-1","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 15/12-1 was drilled in order to\r\nevaluate the Paleocene and Jurassic formations on a closed structure 5 km\r\nnortheast of the Maureen Field which is located just across the UK-Norwegian\r\nmedian line in UK territory. The principle objectives of the 15/12-1 test were\r\nthe Paleocene and Dogger (Hugin Formation) sandstones where oil accumulations\r\nhad been proven in the Maureen field 5 km to the southwest on British sector.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well is Reference Well for the\r\nSleipner Formation.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 15/12-1 was spudded with the\r\nsemi-submersible installation Ross Rig on 7 July 1975 and drilled to a total\r\ndepth of 3269 m in Triassic fine-grained sandstone with green and red-brown\r\nshale of the Skagerrak Formation. The well was drilled with a lignosulphonate\r\ntype of mud.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe Paleocene sandstone at 2633 m to 2643\r\nm in 15/12-1 was encountered 6 m lower than in the Maureen no. 2 well. The\r\nsandstone is medium to coarse grained with good porosity (26%), but water wet.\r\nThe Hugin sandstone was encountered some 50 m higher than in the Maureen no. 2\r\nwell. Oil shows were encountered on the cores from the Hugin Formation, but log\r\nanalysis and FIT proved the sandstone to be water bearing. The logs also\r\nindicated shows of hydrocarbon in the Late Cretaceous limestone at 2925 - 2955\r\nm, but log porosity was calculated from 0 to 6%, too tight to obtain a sample.\r\nThe Late Triassic has good sand development that could be adequate for\r\naccumulation of hydrocarbons. During the drilling of the Triassic section, the\r\nbackground gas in mud and cuttings was near zero.\u003c/p\u003e\r\n\r\n\u003cp\u003eEight cores were cut in the well.\r\nPaleocene sands (Lista and Maureen Formations) were cored from 2612.1 m to\r\n2651.1 m. One core was cut in the Heather Formation from 3067 m to 3073.3 m;\r\none core was cut from the Hugin Formation into the Sleipner Formation from\r\n3125.7 m to 3143.7 m. The Sleipner Formation was further cored in three cores\r\ndown to 3183 m. On the bas","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"93","properties":{"OBJECTID":93,"wlbNpdidWellbore":95,"wlbName":"34/10-14","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 34/10-14 was drilled on a horst\r\nblock in the north-eastern part of the Gullfaks field. The objectives of the\r\nwell were to prove the structural position of the middle- and early Jurassic\r\nsandstones and to establish the oil-water contact in the Brent Group in this\r\npart of the field.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 34/10-14 was spudded with\r\nthe semi-submersible installation Ross Rig on 24 December 1981 and drilled to\r\nTD at 2647 m in the Triassic Hegre Group. Significant downtime (17% of total\r\nrig time) was caused by the combined effect of bad weather and the need to pull\r\nthe BOP three times to detect leaks. The well was drilled with\r\ngel/lignosulphonate/seawater mud all through.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWeak shows on limestone and claystone\r\ncuttings were recorded intermittently from 1506 m in the Hordaland down to top\r\nShetland Group at 1729 m. Sandstones of the Ness Formation were oil-bearing\r\nfrom 1908 m to the oil-water contact, indicated by pressure measurements and\r\nlogs to be at 1972 m. This corresponds to the OWC found in the wells 34/10-3, 5\r\nand 8. Shows on cores continued down to 2002 m.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eTen cores were recovered, nine in the\r\ninterval from 1889 to 2047m KB and one core from 2210 to 2228 KB. RFT fluid sampling\r\nwas performed at 1917.5 m and 1961.5 m but the fluids recovered were not\r\nrepresentative for the reservoir fluid. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was permanently abandoned on 19\r\nMarch 1982 as an oil appraisal well.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eTesting\u003c/span\u003e\u003c/b\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eOne drill stem test was performed in the\r\ninterval 1933.5 m to 1937.5 m in the Ness Formation. The tes","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"94","properties":{"OBJECTID":94,"wlbNpdidWellbore":96,"wlbName":"2/11-4","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 2/11-4 was drilled on the Lindesnes\r\nRidge in the Southern North Sea. The objective was to delineate the Valhall\r\ndiscovery made by well 2/8-6 in 1975. The target was the Late Cretaceous chalks\r\nin the Tor and Hod formations.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 2/11-4 was spudded with\r\nthe jack-up installation Dyvi Beta on 20 March 1978 and drilled to TD at 2858 m\r\nin the Late Cretaceous Rødby Formation. No significant problems were\r\nencountered in the operations. The well was drilled with sea water and hi-vis\r\npills down to 390 m, with sea water/gypsum mud from 390 m to 2559 m, and with Magcobar\r\noil based "Oilfaze" mud from 2559 m to TD. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well penetrated a normal Quaternary\r\nand Tertiary sequence. Good oil shows with free oil present in the mud was\r\nobserved in siltstone and claystone from 1400 to 1800 m in the upper part of\r\nthe Hordaland Group. Occasional spotty oil shows in claystones and limestones\r\n(direct and cut fluorescence) were recorded from 1800 to 2250 m. The Cretaceous\r\nChalk was penetrated at a depth of 2587 meters some 23 meters higher than\r\nprognosed. The objective Tor Formation reservoir proved to be hydrocarbon\r\nbearing with a gross pay section of 18 meters and oil saturations up to 62%. Hydrocarbon\r\nsaturation in the Hod Formation was insignificant due to low elevation on the\r\nstructure. Fair to excellent oil shows were seen in the reservoir section down\r\nto 2607 m. Below 2607 m scattered poor shows were seen down to 2619 m.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eCoring commenced at 2582.5 meters, 4.5\r\nmeters above top Chalk, to ensure recovery from the uppermost part of the pay\r\nsection. A total of 5 conventional cores were attempted over the interval\r\n2582.5 m to 2619 m. Cores no 1 and 2 ha","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"95","properties":{"OBJECTID":95,"wlbNpdidWellbore":97,"wlbName":"2/4-3","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 2/4-3 (named 2/4-2X by operator\r\nPhillips) was drilled to appraise the 2/4-2 Ekofisk discovery in the southern\r\nNorwegian North Sea. The target was to test the Tertiary and the top of the\r\nLate Cretaceous. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 2/4-3 was spudded with the\r\nsemi-submersible installation Ocean Viking on 27 January 1970 and drilled to TD\r\nat 3431 m in the Late Cretaceous Tor Formation. The well was planned vertical,\r\nbut the deviation was significant. Maximum deviation was 1 deg\u00A0 at 618 m, 3\r\ndeg\u00A0 at 1077 m, 11.5 deg\u00A0 at 1316 m, 16.4 deg\u00A0 at 1605 m, 10 deg\u00A0 at 2167 m, 4\r\ndeg\u00A0 at 3002 m, and 1.7 deg at 3292 m. This indicates that TVD RKB is ca 30 m\r\nshallower than MD RKB at TD, but exact records are not available. The well was\r\ndrilled with seawater and hi-vis mud down to 619 m, with CaCl2 / Dextrid\r\n(modified potato starch) from 619 m to 1695 m, and with lignosulphonate /\r\nseawater from 1695 m to TD. One - four percent diesel was added to the mud\r\nbelow 619 m. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe Danian chalk (Ekofisk Formation) was\r\nencountered at 3090 m, and the Late Cretaceous chalk (Tor Formation) at 3253 m.\r\nThe formations were tested hydrocarbon bearing from 3124 m to 3319 m.\u003c/p\u003e\r\n\r\n\u003cp\u003eEighteen conventional cores were cut in\r\nthe well. Core 1was cut in the interval 1705 - 1717 m with only 0.6 m core\r\nrecovered. Cores 2 - 13 were cut in the Danian chalk (Ekofisk Formation), while\r\ncores 14 - 18 were cut in the Maastrichtian chalk (Tor Formation). No fluid\r\nsamples were taken on wire line.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 31\r\nMay 1970 as an oil appraisal.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eTen drill stem tests were carried out\r\nthrough perforations in the 7" liner. DST 1 and 2 tested the intervals\r\n3352 - 3362 m and 3331 - 3341 in the in the Tor Formation. They produced only\r\nwater. DST 3 to 9 tested different zones in the interval from 3124 to 3319 m in\r\nthe Ekofisk and Tor Formations. They produced gas and oil. The oils were in the\r\nrange 33.2 to ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"96","properties":{"OBJECTID":96,"wlbNpdidWellbore":98,"wlbName":"30/11-4","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 30/11-4 was drilled north-east of\r\nthe Frigg area in the Fensal Sub-basin in the North Sea. Previous well 30/11-3\r\nwas abandoned at top Statfjord Group for technical reasons, due to high\r\npressures, without being production-tested. Well 30/11-4 was then proposed as a\r\nvirtual re-drill, only some 400 m NE of 30/11-3. The objective of the well was\r\nto test the hydrocarbon potential of the Middle Jurassic Vestland Group\r\nsandstones and the Early Jurassic Statfjord Group sandstones in a westward\r\ntilted horst block\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 30/11-4 was spudded with the\r\nsemi-submersible installation Dyvi Delta on 25 January 1984 and drilled to TD\r\nat 5255 m in Late Triassic sediments belonging to the Statfjord Group . At 2179\r\nm the drill string parted, leaving a 24 m fish in the hole. After unsuccessful\r\nfishing the well was sidetracked from 1918 m. The well was drilled with\r\nbentonite and brack water down to 813 m, with KCl/polymer mud from 813 m to\r\n4205 m, with gel/lignosulphonate/lignite mud from 4205 m to 5059 m, and with\r\ngel/polymer lignite mud from 5059 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 30/11-4 penetrated water bearing\r\nreservoir sands in the Tertiary Frigg and Heimdal formations. The Vestland\r\nGroup was penetrated at 3434 m. This section had oil shows at 3434 m to 3470 m,\r\nwhere some oil emulsion was retrieved by RFT, at 3514 m to 3550 m, and at 3635\r\nm to 3650 m. An anomaly in the reservoir pressure occurred at about 3580 m where\r\na siltstone/claystone interval possibly acts as a seal/pressure barrier. A total\r\nof 615 m of sands and shales assigned to the Statfjord Group, between 4640 m\r\nand TD in the well. Log interpretation pointed towards the presence of at least\r\n75 metres of sands with porosities up to 20% and water saturations as low as\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"97","properties":{"OBJECTID":97,"wlbNpdidWellbore":99,"wlbName":"7120/12-4","wlbHistory":"\r\n\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 7120/12-4 is located on the\r\nnorthern margin of the Finmark Platform ca 9 km south of the 7120/12-2 gas\r\ndiscovery. The primary objective of the well was to test a sandstone reservoir\r\nof Late Permian age on the platform area. The reservoir prospect was seen as\r\nmerging of two shale/limestone units separated by the reservoir sandstone.\r\nThese shale units were seen on the seismic as the "platform" event\r\nand the "sub crop" event at 1160 ms and 1260 ms respectively. The sub\r\ncrop event was interpreted as a carbonate shelf edge and the reservoir as being\r\ncomposed of shallow marine sandstones. The cap rock was the massive overlying\r\nTriassic shale and the trap was sourced by migration from mature Late Triassic\r\nand Permian shales in the Hammerfest basin. Basement was prognosed at 2430 m.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 7120/12-4 was spudded with the\r\nsemi-submersible installation Treasure Scout on 18 February 1984 and drilled to\r\nTD at 2199 m in the Late Carboniferous Ugle Formation. No significant problems\r\noccurred during operations. The well was drilled with seawater and hi-vis pills\r\ndown to 666 m and with KCl/polymer/gypsum mud from 666 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well penetrated an interval of\r\nQuaternary to Tertiary age sediments, which directly overlay rocks of Middle to\r\nLate Triassic age (Snadd Formation) at 435 m. A Late Permian succession was\r\npenetrated from 1366 m to 2118 m and consisted of alternating beds of\r\nclaystone/siltstone/sandstone (Ørret Formation) and cherty limestone (Røye\r\nFormation). The "platform" event was penetrated at 1469 m and\r\ncorrelate with a 33 m thick Røye sequence. The prognosed reservoir was\r\nencountered at 1502 m and was composed of fine to occasionally very\r\ncoarse-grained sandstone belonging to the Ørret Formation. The reservoir was\r\nwater bearing with a gross interval of 56 m and net sand was 55 m. Average\r\ncalculated porosity was 18 %. The sub crop event was a second Røye sequen","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"98","properties":{"OBJECTID":98,"wlbNpdidWellbore":100,"wlbName":"31/3-2","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 31/3-2 was drilled immediately to\r\nthe southeast of a fault that was interpreted as a boundary fault between Troll\r\nWest and Troll East. The main objectives of the appraisal well 31/3-2 were to\r\ndetermine if hydrocarbons were present on the downthrown south side of the\r\nfault, to determine the contacts, and to determine the degree of communication\r\nacross the fault plane. A test would be performed in the case of moveable\r\nhydrocarbons, in order to observe boundary effects where the pay zone is narrow\r\nand thin. The well was planned to reach total depth in the Early Jurassic Drake\r\nFormation at 2050 m if drilling through the "boundary fault". In the\r\ncase of drilling entirely within the hanging-wall block the total depth was\r\nestimated to 2130 m.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 31/3-2 was spudded with the\r\nsemi-submersible installation Treasure Seeker on 5 March 1984 and drilled to TD\r\nat 2090 m in claystones of the Early Jurassic Drake Formation. No significant\r\ntechnical problems occurred during drilling and testing. The well was drilled\r\nwith pre-hydrated gel/seawater with sweeps of high viscous mud down to 629 m\r\nand with KCl/polymer mud from 629 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe Sognefjord Formation (1567 - 1706 m)\r\nwas found oil bearing down to 1578.5 m where the oil/water contact was\r\nestablished. The oil-bearing reservoir consisted of very fine to very\r\ncoarse-grained sandstones. They are friable to loose with only traces of\r\nsiliceous or calcareous cement. The total net sand in the Sognefjord Formation\r\nwas calculated to 132 m out of 139 m gross thickness, giving a net/gross ratio\r\nof 0.95 and an average porosity of 26.6%. A thin (0.5 m) gas cap could be\r\npresent on top of the oil column. This was identified from LDT/CNL logs and was\r\nalso consistent with the GOR development during the test, but was not confirmed\r\nby RFT data. There were no oil shows above the Sognefjord Formation, and no oil\r\nshows below1595 m, and the Middle to Early Jurassic sa","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"99","properties":{"OBJECTID":99,"wlbNpdidWellbore":101,"wlbName":"31/5-3","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 31/5-3 was drilled in the southern\r\npart of the Troll West Field. The main objectives were to appraise and test the\r\nreservoir qualities and the lithology of the Late Jurassic Sognefjord\r\nFormation. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 31/5-3 was spudded with the\r\nsemi-submersible installation Treasure Saga on 10 April 1984 and drilled to TD\r\nat 2250 m in the Late Jurassic Drake Formation. At 1426 m circulation was lost,\r\nand 450 bbls mud was lost to formation before the well was stabilized. The well\r\nwas drilled with spud mud down to 950 m, with KCl/polymer mud from 950 m to\r\n1497 m, and with a Pro-wate/NaCl-brine/pro-salt mud from 1497 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well proved the existence of a\r\nstratigraphy ranging from Lower Jurassic to Quarternary. The Tertiary and\r\nQuaternary sections were mainly composed of claystones, with a minor sand\r\ndeveloped in Pleistocene at the base of the Nordland Group. The Jurassic was\r\ncomposed of sandstone and siltstones in the Viking and Brent Groups, and mainly\r\nclaystone with an interbedded sandstone layer in the Dunlin Group. One major\r\nunconformity was found between Early Portlandian and Maastrichtian. Four other\r\nunconformities were also observed in the well, from Aalenian to Bathonian, from\r\nEarly Kimmeridgian to Early Portlandian, from Late Oligocene to Pliocene, and\r\none intra-Oligocene.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe Sognefjord Formation was hydrocarbon\r\nbearing with a 39.5 m hydrocarbon column, of which 17.5 m was gas and 22 m was\r\noil. Top reservoir was found at 1555 m, the GOC was at 1572.5 m, and the OWC at\r\n1594.5 m. Oil shows persisted further down, but decreased from 1595 m and\r\ndisappeared below 1622 m. No other interval in the well was hydrocarbon\r\nbearing.\u003c/p\u003e\r\n\r\n\u003cp\u003eThree cores were cut from 1550 m to\r\n1622.5 m in the Late Jurassic Sognefjord Formation. FMT gas samples were taken\r\nat 1557 m and 1567. Three more FMT fluid samples were taken in the oil zone at\r\n1577 m, 1591 m, and at 1592 m.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"100","properties":{"OBJECTID":100,"wlbNpdidWellbore":102,"wlbName":"30/9-3 A","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 30/9-3 A is a sidetrack to well 30/9-3\r\non the Gamma West structure on the Oseberg Fault Block in the northern North\r\nSea. The primary objective of 30/9-3 was to find hydrocarbon accumulations in\r\nthe Middle Jurassic Brent Group. Secondary objective was to find additional\r\nhydrocarbon accumulations in the Early Jurassic. Planned TD was ca 75 m below a\r\npossible intra Triassic marker to a depth of 4188 +/- 100 m. Well 30/9-3\r\ndiscovered oil in the Brent Group, but reached only 3113 m in the Drake\r\nFormation due to fish in the hole. For the same reason no wire line logs were\r\nrun below 1713.5 m.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eSidetrack well 30/9-3 A was drilled to\r\ncomplete the well programme.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 30/9-3 A was kicked off on 26\r\nFebruary 1984, from a window from 1539 to 1562 m in the 13 3/8" casing.\r\nThe well was drilled to TD at 4300 m (4008 m TVD) in the Late Triassic Lunde\r\nFormation using the semi-submersible installation Nortrym. No significant\r\nproblem was encountered in the operations. The well was drilled with\r\nInvermul/EZmul Oil Based Mud from kick-off to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe Ness Formation (2853.5 - 3059 m, 2717.3\r\n- 2890 m TVD) was encountered at a horizontal distance of 538 m to the west of\r\nthe 30/9-3 well. The top of the formation had been subjected to erosion and\r\nlacked the sandstone units which were found in the upper part of the 30/9-3\r\nwell. The lithology was alternating sandstones, siltstones and shales with beds\r\nof coal. The sandstones were generally very fine to fine grained, locally\r\nmedium grained, and occurred often as normally graded beds.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe Ness Formation was found oil bearing\r\ndown to 3000 m (2840m TVD). No oil/water contact c","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"101","properties":{"OBJECTID":101,"wlbNpdidWellbore":103,"wlbName":"33/5-1","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThe objective of the well, located on the\r\nMakrell horst on the northern margin of the East Shetland Basin, was to test\r\ntwo possible sandstone reservoirs of Triassic and Permo-Triassic age\r\nrespectively. The first of these reservoirs was prognosed to be an Early\r\nTriassic massive sandstone reservoir. Correlation with the U.K. well 211/13-1\r\nindicated that this sandstone could be divided into two main sequences both\r\nwith increasing silt and clay content in the lower parts. These sands were\r\nthought to be deposited in a braided alluvial system. The second was prognosed\r\nto be Permo-Triassic fluvial sandstone similar to the higher reservoir but\r\nseparated from it by lacustrine or lagoonal shales, marls and limestones. The\r\nwell was planned to reach total depth below a seismic marker at approximately\r\n3825 m. \u003c/p\u003e\r\n\r\n\u003cp\u003eWell 33/5-1 is reference well for the\r\nTriassic Teist and Lomvi Formations.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 33/5-1 was spudded with the\r\nsemi-submersible installation Treasure Seeker on 19 July 1979 and drilled to TD\r\nat 3829 m in the Early Triassic Teist Formation, interpreted to be close to the\r\nseismic "A" marker. A gas leakage from a shallow gas zone at 480 m to\r\n490 m between the 20" and 30" casing was observed sporadically\r\nthroughout drilling of the well. The leakage was stopped when the gas zone were\r\nsqueezed off with cement during abandonment of the well. An 18 1/2" hole\r\nwas first drilled to 1516 m. When pulling out of the hole the string got stuck\r\nat 1226 m and the well was sidetracked from 1019 m to 1071 m. Logs are from the\r\nsidetrack. Further drilling went without significant problems. The well was\r\ndrilled with seawater/bentonite/CMC down to 1540 m. Diesel and lubricants were\r\nadded to the mud when attempting to free the stuck pipe. A\r\nlignosulfonite/lignite mud was used from 1540 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eA sequence of interbedded limestones of\r\nEarly Tertiary to Late Cretaceous age (Late/Middle Paleoc","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"102","properties":{"OBJECTID":102,"wlbNpdidWellbore":104,"wlbName":"7120/7-3","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 7120/7-3 is located on the\r\nRingvassøy-Loppa Fault Complex west of the Hammerfest Basin and the Snøhvit\r\nField. The primary objective of the well was to test possible hydrocarbon\r\naccumulations in sandstones of Middle to Lower Jurassic age. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was spudded with the\r\nsemi-submersible rig West Vanguard on 18 March 1984 and drilled to TD at 3062 m\r\nin the Early Jurassic Nordmela Formation. The well was drilled with seawater\r\nand bentonite down to 331 m, with lignosulfonate/gypsum/polymer mud from 331 m\r\nto 715 m, with gypsum/polymer mud from 715 m to 1720 m, with polymer mud from\r\n1720 m to 2625 m, and with lignite/polymer mud from 2625 m to TD. The 36"\r\nhole had to be reamed before setting of the 30" casing. During cementing\r\nof 20" casing returns were lost. Technical problems occurred when testing\r\nthe BOP stack before drilling out of the 20" casing shoe, and after the 13\r\n3/8" casing job. Mud problems occurred when drilling out of the 20"\r\ncasing shoe due to cement contamination. Because of tilted wellhead two\r\nattempts to run in the casing was needed. When running in an 8 1/2" bit to\r\nperform leak off test below the 9 5/8" casing shoe, problems occurred\r\ngetting the bit through wearbushing in wellhead. After this 4 kg junk was\r\nrecovered from the hole. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe well penetrated Tertiary, Cretaceous,\r\nand Jurassic sediments. Lithology down to 2759 m (Base Cretaceous) was\r\ndominantly claystone with stringers of sandstone/siltstone/Limestone/Dolomite.\r\nThe Late Jurassic Hekkingen Formation from 2759 m to 2889 m consisted of shale\r\nwith stringers of siltstone and limestone and traces of sand. Pyrite was seen\r\nin trace amounts in the upper part and was abundant in the lower part of the\r\nsequence. From 2889 m to TD, in the Middle to Early Jurassic, the lithology was\r\nsandstone with shale interbeds. Trace to faint shows were recorded in claystone\r\ncuttings below 1200 m. Good show","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"103","properties":{"OBJECTID":103,"wlbNpdidWellbore":105,"wlbName":"31/6-5","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 31/6-5 was drilled in the southern\r\npart of the Troll East gas province, 30 m from well 31/6-4, which was junked\r\nfor technical reasons. The main purpose was to appraise and test possible oil\r\nand gas accumulations in sandstones of Late to Middle Jurassic age, and to give\r\nfurther information about lateral facies changes within the reservoir\r\nsandstones. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eAppraisal well 31/6-5 was spudded with\r\nthe semi-submersible installation Deepsea Bergen on 5 March 1984 and drilled to\r\nTD at 2082 m in the Early Jurassic Drake Formation. In the 26" hole lost\r\ncirculation occurred at 653 m, two cement plugs were set. Several wiper trips\r\nwere taken due to tight hole. After setting of the 20" casing, the BOP had\r\nto be repaired due to leaking during pressure testing. A drilling break\r\noccurred at 1476 m in the 12 1/4" hole. The well was drilled with the spud\r\nmud from the previous hole (31/6-4) treated with CMC-EHV down to 389 m, with\r\nseawater/gel mud from 389 m to 663 m, with KCl/polymer mud from 663 m to 1720\r\nm, and with seawater/gel/CMC mud from 1720 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eSandstone of Late to Middle Jurassic age\r\n(Sognefjord Formation) was encountered at 1518 m with a 52 m gas column and a 4\r\nm oil column. The gas/oil contact was at 1570 m and the oil/water contact at\r\n1574 m. Oil shows were recorded on sidewall cores on top Fensfjord Formation\r\nsandstone from 1722 m to 1726 m and on a sandstone SWC from 2010 m in the Ness\r\nFormation. Ten cores were cut from 1470 m to 1721 m in the Late to Middle Jurassic\r\nsequence (Heather Formation to Fensfjord Formation). One FMT fluid sample was\r\ntaken in the oil zone 1571.5 m. Geochemical analyses showed the oil to be\r\nbiodegraded.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 16\r\nMarch 1984 as a gas and oil appraisal.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThe Sognefjord Formation was tested\r\nthrough gravel pack from the interval 1558 m to 1568 m. The first test gave a\r\nnon-representative","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"104","properties":{"OBJECTID":104,"wlbNpdidWellbore":106,"wlbName":"31/2-14","wlbHistory":"\r\n\r\n\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eAppraisal well 31/2-14 was drilled on the\r\nnorth-western margin of the Troll field. The main objectives of the well were\r\nto demonstrate the production potential for oil in the northern part of the\r\nTroll oil province, to evaluate the proposed template development scheme and to\r\nconfirm the predicted extension of high energy progradation sands in the\r\nnorthern region. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 31/2-14 was spudded with the\r\nsemi-submersible installation Borgny Dolphin on 23 April 1984 and drilled to TD\r\nat 1725 m in the Middle Jurassic Fensfjord Formation. The site survey before\r\nspud showed, as usual for the area, a seabed with numerous pockmarks (12\r\npockmarks/km3 on average). After setting the 13 3/8" casing shoe at 1498 m\r\na leak in the kill-line was discovered, leading to repairs of the BOP and\r\nreplacement of the marine riser. After 10 days lost time normal operations\r\ncould resume. The well was drilled with seawater and hi-vis pills down to 814\r\nm, with KCl/polymer mud from 814 m to 1513 m, and with chalk mud from 1513 m to\r\nTD. \u003c/p\u003e\r\n\r\n\u003cp\u003eNo sands were encountered above the\r\nJurassic.The well encountered hydrocarbons in the Late Jurassic Sognefjord\r\nFormation. Top reservoir was penetrated at 1533 m (1508 m SS). The GOC was at\r\n1566 m (1541 m SS) and the FWL was at 1592 m (1567 m SS). The oil-bearing\r\ninterval consists of medium to low quality sands with a very clean layer (7m)\r\nsome 3 m above the OWC. Below 1595 m (top Heather Formation) the sands are\r\nmicaceous. The core measured permeability values range from 10 mD to 10 Darcy.\r\nIn the gas bearing part of the cored interval no to weak fluorescence was\r\nrecorded. In the oil zone (1561 - 1592 m) the fluorescence varied from weak to\r\nstrong. Below 1594 m no fluorescence was recorded. Seven cores were cut from\r\n1535 m to 1599 m in the Late Jurassic sequence. No samples were taken on wire\r\nline.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 21\r\nJune as a gas and oil appraisal.\u003c/p\u003e\r\n\r\n\u003cp\u003e","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"105","properties":{"OBJECTID":105,"wlbNpdidWellbore":107,"wlbName":"7120/9-2","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 7120/9-2 is located in The\r\nHammerfest Basin, west of the Albatross discovery, later included in the\r\nSnøhvit Discovery. The structure comprised a dome like feature transected by a\r\nfew major N-S, and E-W oriented faults. The 7120/9-2 well was drilled in a\r\ncrestal position on this structure and planned total depth was 5500 m in rocks\r\nof Permian/Carboniferous age. The objective of well 7120/9-2 was to test\r\nPermian reservoirs confined by Permian Marker III (4810 m ±150 m), Permian\r\nMarker II (4745 m  ±50 m), and Permian Marker I (4620 m ±150 m) for\r\nhydrocarbons. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 7120/9-2 was spudded with the\r\nsemi-submersible rig Treasure Scout on18 April 1984 and drilled to a total\r\ndepth of 5072 m in limestones, siltstones and cherts the Permian Røye\r\nFormation. The well was drilled with Bentonite and seawater to 381 m, with\r\nKCl/Polymer mud from 381 m to 1165 m, with Lignosulfonate /Polymer mud from\r\n3900 m to 4270 m, and with Gel/Lignosulfonate mud from 4270 m to TD. A 17\r\n1/2" pilot hole was drilled to 1165 m, before underreaming to 26"\r\nhole. The underreamer was lost in the hole and the well was sidetracked at 1070\r\nm. While running the 20" casing, it parted but was recovered. Before\r\ndrilling the 12 1/4" hole section two cement squeeze jobs were performed\r\ndue to a low leak off test. Due to lost circulation the 9 5/8" casing was\r\nset at 4270 m. Before drilling the 8 3/8" hole section a cement squeeze\r\njob was performed due to a low leak off test. Due to lost circulation the\r\n7" liner was set at 4791 m. Two cement squeeze jobs were performed. At\r\n5072 m lost circulation problems occurred, the well was logged and plugged back\r\nand terminated earlier than prognosed. \u003c/p\u003e\r\n\r\n\u003cp\u003eSome of the Jurassic sandstone intervals\r\nencountered between 1970 m and 2290 m were gas bearing, with structural closure\r\nat the point where the well bore penetrated the formation. The intervals were\r\nsubdivided into thr","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"106","properties":{"OBJECTID":106,"wlbNpdidWellbore":108,"wlbName":"6406/3-1","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 6406/3-1 is located in the southern\r\nend of the block, west of the Tyrihans S ør Field on the Mid Norway continental\r\nshelf. The primary objective was to test the reservoir potential of the Middle\r\nJurassic sandstones. Secondary objectives were the Early Jurassic sandstones,\r\npenetration of the Triassic Grey Beds and Red Beds, and sampling of potential\r\nsource rocks.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 6406/3-1 was spudded with the\r\nsemi-submersible installation Ross Isle on 27 April 1984 and drilled to TD at\r\n4902 in the Late Triassic Red Beds. The well was drilled with seawater and gel\r\n(bentonite/soda) down to 962 m, with gypsum/lignosulphonate mud from 962 m to\r\n3775 m, and with gel/lignosulphonate/lignite mud from 3775 m to TD. At 4498 m a\r\npill of IMCO SPOT/ Pipe Lax was added to free the pipe, which was stuck.\u003c/p\u003e\r\n\r\n\u003cp\u003eA hydrocarbon bearing Middle Jurassic\r\nsandstone was encountered at 3782 m, but a drill stem test proved only low\r\nconcentration of gas in a water phase. The pore pressures in the well were\r\nhigher than expected and the Middle Jurassic sandstone, which was believed to\r\nhave a pore pressure equivalent to 1.14 s.g., proved to have a pore pressure\r\nequivalent to 1.82 s.g. Post-well geochemical analyses detected migrated\r\nhydrocarbons frequently below 1650 metres. These shows were seen chiefly as wet\r\ngas/condensate between 2405 - 2585 m and as wet to extremely wet gas at 3665 -\r\n3785 m. Good shows of wet or marginally wet gas were associated with the coals\r\nwithin the Early Jurassic and Trias (Åre Formation).\u00A0 These were suggested in\r\nthe geochemical report to be in-situ generated and not migrated.\u003c/p\u003e\r\n\r\n\u003cp\u003eFour cores were cut in the well: three\r\nfrom 3783 m to 3847 m in Middle Jurassic Sandstones (Garn Formation) and one\r\nfrom 4539 m to 4549 m in the "Coal Unit" (Åre Formation). An RFT\r\nfluid sample was taken at 3784.5 m in the Garn Formation.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 14\r\nAugust 1984 as a well with strong ga","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"107","properties":{"OBJECTID":107,"wlbNpdidWellbore":109,"wlbName":"2/1-6","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 2/1-6 is located on the northern\r\nside of the Gyda structure on the Cod Terrace in the North Sea.\u003c/span\u003e\u003cspan\r\nlang=EN-GB\u003e \u003c/span\u003e\u003cspan lang=EN-GB\u003eThe main target was the Late Jurassic\r\nSandstone, informally called the Gyda sandstone member. The well was located\r\nsuch that it should prove the oil water contact of the 2/1-3 oil discovery, and\r\nby this establish whether 2/1-3, 2/1-4 and 1/3-3 all have encountered the same\r\noil accumulation on the two sides of the saddle point. It should also test\r\nfurther the extent and the quality of this Upper Jurassic reservoir.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 2/1-6 was spudded with the\r\nsemi-submersible installation Dyvi Alpha on 30 April 1984 and drilled to TD at 4583\r\nm (4588 m loggers depth), one metre into Late Triassic sediments of the Skagerrak\r\nFormation. The well was drilled with seawater and pre-hydrated bentonite spud\r\nmud down to 635 m, with KCl/polymer mud from 635 m to 3424 m, with\r\nlignosulfonate mud from 3424 m to 4124 m, and with high temperature polymer mud\r\nfrom 4124 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe Gyda sandstone member was penetrated\r\nat 4173 m logger's depth. The reservoir is 205 metres thick, generally very\r\nfine to fine grained sandstone, but with a 28 metre thick siltstone\r\nincorporated in the uppermost part. Reservoir properties were very variable.\r\nReasonable reservoir properties were found near the top of the reservoir. They were\r\npoor in an upper siltstone zone, in an intermediate 77 metre thick quartz\r\novergrowth zone and at the base of the 2/1-3 sand where it shaled out into the\r\nFarsund Formation. Shows were recorded from 4174 to 4178 m in a sandstone that\r\nhad very low permeability, and could not be tested. Minor patchily developed\r\nshows were observed from 4178 down to 4203 m, all within","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"108","properties":{"OBJECTID":108,"wlbNpdidWellbore":110,"wlbName":"30/6-15","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 30/6-15 was drilled on the Gamma\r\nNorth structure west of the Oseberg Alpha structure. Gamma North is a NNW-SSE\r\ntrending fault block down-faulted to the adjacent Alpha structure. The primary\r\nobjective was to find hydrocarbon accumulations in the Statfjord Group. The\r\nsecondary objective was to test the hydrocarbon potential in the Cook\r\nFormation. The total depth of the well was planned ca 270 m into the Triassic\r\nat a depth of ca 3950 m, corresponding to ca 3200 m TVD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 30/6-15was spudded with the\r\nsemi-submersible installation Treasure Seeker on 2 May 1984 and drilled\r\ndeviated to TD at 3972 m (3200 m TVD) at a position ca 2180 meters west of the\r\nsurface position. Operations suffered from comparatively much down time due to\r\nhole problems and equipment repairs. The 8 3/8" and 6" sections in\r\nparticular suffered hole problems and difficult logging. The well was drilled\r\nwith spud mud down to 195 m, with gel/sea water from 195 m to 617 m, with\r\nSafeMul oil based mud from 617 m to 3005 m, and with NaCl/polymer mud from 3005\r\nm to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe Etive Formation (2884 - 2902 m, 2358\r\n- 2372 m TVD) truncated by Cretaceous strata was found water bearing.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo Cook Formation reservoir was\r\nencountered. The Statfjord Formation (3241 - 3548 m, 2641.5 -2878.5 m TVD)\r\nsandstones were found gas bearing down to 3313 m (2697 m TVD), and oil bearing\r\ndown to 3348 m (2723.5 m TVD). An oil/water transition zone is seen down to\r\n3359 m MD (2732 m TVD). The lithology of the hydrocarbon bearing interval was\r\npredominantly sandstones with some interbeds of claystones/shales. Net pay in\r\nthe gas zone was calculated on logs to 67.4 m giving a net to gross ratio of\r\n0.94. Ne","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"109","properties":{"OBJECTID":109,"wlbNpdidWellbore":111,"wlbName":"34/7-1","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe wildcat 34/7-1 was drilled on the\r\nE-structure northeast in block 34/7, on a location ca 9 km south-south west of\r\nthe 34/4-1 Snorre Discovery well in the northern North Sea. The continuation of\r\nthis structure was explored by well 34/4-4. The main objective of 34/7-1 was Late\r\nTriassic sandstones, which proved hydrocarbon bearing in 34/4-1 and 34/4-4. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 34/7-1 was spudded with the\r\nsemi-submersible installation Vildkat on 9 May 1984 and drilled to TD at 2905 m\r\nin the Late Triassic Lunde Formation. The 26" hole was drilled and logged\r\nfirst as a 17 1/2" pilot hole to 1106 m as a precaution against shallow gas\r\nthen opened up to 26" by using underreamer. Tight spots occurred in the\r\n26" hole section. In the 17 1/2" hole the string got stuck at 1274 m.\r\nThe string had to be backed off and was fished out of the hole. Some tight\r\nspots occurred in this section too. When running the 9 5/8" casing, lost\r\nreturns were experienced three times and the casing was pulled out of the hole.\r\nA velocity log was run, and the well was plugged back to 2640 m by setting two\r\ncement plugs and the 9 5/8" casing was landed at 2632 m. The well was\r\ndrilled with seawater and bentonite down to 1106 m and with polymer/KCl mud\r\nfrom 1106 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe Tertiary and Cretaceous sections were\r\nmainly composed of claystones, with sand development in lower the Pliocene and\r\nin the Late Miocene. The Triassic consisted of sandstones alternating with\r\nsiltstones, claystones and minor marl.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eA major unconformity is observed at 2392\r\nm between the Late Triassic and the Lower Cretaceous. Apart from this, four\r\nother unconformities are observed in the well, one in Cretac","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"110","properties":{"OBJECTID":110,"wlbNpdidWellbore":112,"wlbName":"16/11-1 S","wlbHistory":"\r\n\r\n\u003cp\u003eWell 16/11-1 S is located in the Danish\r\nNorwegian Basin. The objective of the well was to test the hydrocarbon\r\npotential of the Tertiary, Mesozoic and Permian sediments. Specifically,\r\nTertiary sandstones, Cretaceous sandstones and limestones, Jurassic and\r\nTriassic sandstones, Permian carbonates and Permian Rotligendes sandstone were\r\nconsidered to be prospective.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 16/11-1 S was spudded with\r\nthe semi-submersible installation Ocean Viking on 17 July 1967 and drilled to\r\nTD at 3050 m (ca 3020 m TVD RKB) in the Late Permian Zechstein Group. The well\r\nis classified as deviated, but was not meant to be. During reaming operation at\r\nabout 1463 m the hole was accidentally sidetracked. This was not discovered until\r\n13 3/8" casing was set and the cement plug drilled through. Hole deviation\r\nwas then determined to be 16 deg at the casing shoe. In order to prevent a\r\ndogleg the deviation was gradually decreased to 12.5 deg at about 2322 m and\r\nstabilized at an average of 12 deg to TD. The dip meter log indicates that the\r\nhole drifted in a N 45 deg E direction. While drilling at 2952 m the drill\r\nstring stuck and a fish was left in the hole. A cement plug was set and the\r\nfish was bypassed by sidetracking with jet action from the bit. Upon reaching\r\n2952 m, the pipe stuck a second time, which resulted in leaving a new fish. A\r\nsecond cement plug was set and the hole sidetracked using a Neyrpic turbine\r\ndrill. The pipe stuck a third time at 2954 m and another fish was left. The\r\nhole was again sidetracked and mud weight increased to about 16 ppg. Drilling\r\nthen continued to TD, before 9 5/8" casing was set. Circulation was lost\r\nimmediately after drilling through the 9 5/8" casing shoe at 2957 m. Five\r\nDiaseal "M" squeezes and five DOC squeezes were performed in an\r\nattempt to regain circulation with a 16.0 ppg mud, but all attempts were\r\nunsuccessful. A Drispac/Flosal/Desco mud system was used to a depth of 2326 m.\r\nAt this de","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"111","properties":{"OBJECTID":111,"wlbNpdidWellbore":113,"wlbName":"15/12-5","wlbHistory":"\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 15/12-5 was drilled on the Beta\r\nCentral structure ca 3.3 km north-east of the 15/12-4 Varg discovery well in\r\nthe North Sea. Primary objective was the Jurassic sandstones. Secondary\r\nobjective was the Frigg Formation sand and fractured limestone of Cretaceous\r\nage. Seismic anomalies indicated shallow gas. Prognosed TD was 3100 m RKB in\r\nsandstone of Triassic age.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 15/12-5 was spudded with the\r\nsemi-submersible installation Ross Isle on 12 March 1986 and drilled to TD at\r\n3150 m in the Late Triassic Skagerrak Formation. No shallow gas was\r\nencountered. Drilling proceeded without significant problems. The well was\r\ndrilled with Spud mud down to 217 m, with gel/seawater/XC-polymer from 217 m to\r\n619 m, with gypsum/polymer mud from 619 m to 2889 m, and with\r\ngel/lignosulphonate/lignite from 2889 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eTop Cretaceous came in at 2457 m, and top\r\nJurassic at 2841 m. Top of the reservoir, an Oxfordian sandstone, was\r\nencountered at 2918 m with good shows. The OWC was found at 2942 m, 28 m below\r\nthat of well 15/12-4. This is probably due to a flow barrier caused by the\r\nfault system with a maximum throw of ca 100 m that separates the Beta West and\r\nBeta Central structures. Due to FMT pressure measurements and fluid samples,\r\nStatoil decided to go for "sole risk" testing, since Esso denied\r\nparticipating in the testing program.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThree cores were cut in the interval 2892\r\nm to 2967 m with 100% recovery. The core-log depth shifts were small, in the\r\nrange 0.0 to -0.5 m for all three cores. FMT fluid samples were taken at 2919.3\r\nm (oil), 2923.5 m, 2937.0 m (oil), and at 2941.5 m (water mud filtrate and a\r\nlittle oil).\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"112","properties":{"OBJECTID":112,"wlbNpdidWellbore":114,"wlbName":"7119/12-2","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 7119/12-2 is located in the Troms I area in the southwestern part of the Hammmerfest Basin. It was designed to test\r\npossible hydrocarbon accumulations in a seismic closure (Zeta-structure) in the\r\nsoutheastern part of the block. The primary objective of the well was\r\nsandstones of Middle Jurassic age. Secondary objectives were clastics of lower\r\nJurassic and Upper Triassic age.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 7119/12-2 was spudded with\r\nthe semi-submersible installation Ross Rig on 16 April 1981 and drilled to TD\r\nat 1902 m in the Late Triassic Fruholmen Formation. Boulder clays in the top\r\n36" hole caused low rate of penetration and considerable difficulties in\r\nsetting the 30" casing. Gas sands were encountered in the interval from\r\n404-410 m. The 20" casing was set above this sands instead of the planned\r\nsetting depth at 600 m. Due to high gas readings and increasing pore pressure,\r\nthe drilling below 20" casing could not continue to planned 13 3/8"\r\ncasing depth. Hence a 16" liner was set at 590 m. While underreaming below\r\nthe liner, the underreamer failed to close and consequently could not be pulled\r\nto surface. The underreamer was left in the hole and the well sidetracked at\r\n1215 m. The well was plugged back and the BOP-stack pulled when gas bubbles\r\nwere observed coming out of the wellhead. To cure this problem the BOP-stack\r\nwas installed again and previously set cement plugs drilled out to 275 m. A\r\npacker was set inside the 20" casing at 273 m and no more gas was seen coming\r\nfrom the well head. The well was then plugged back and abandoned. The well was\r\ndrilled with spud mud down to 394 m and with gel/lignosulphonate/seawater from\r\n394 m to TD. \u003c/p\u003e\r\n\r\n\u003cp\u003eMiddle Jurassic to Late Triassic\r\nsandstones with good reservoir properties were encountered from 1372 m to TD.\r\nDrill cuttings and extensive coring had oil shows throughout, but RFT pressure\r\ngradients as well as logs and DST proved 100% water ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"113","properties":{"OBJECTID":113,"wlbNpdidWellbore":115,"wlbName":"33/12-5","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 33/12-5 was drilled on the Tampen\r\nSpur in the northern North Sea. It was drilled on the southeast, downfaulted\r\nflank of the Statfjord structure, but on the upthrown block of the major,\r\neast-bounding Statfjord fault. The well was programmed to test in a higher\r\nstructural position, a Triassic sand, found water bearing in the 33/12-2 well,\r\nand to evaluate older, untested section beneath the sand. The Triassic sand in\r\n33/12-2, defined seismically by the "R2" horizon, had been tentatively\r\nidentified as Early Triassic. Secondary objectives were possible Jurassic\r\nreservoirs preserved within this downfaulted area east of the Statfjord Field.\r\nThe 33/12-4 well was a similar test on the east flank of the Statfjord feature.\r\nThis well found a thin Jurassic/Upper Triassic? sand with good porosity, which\r\ntested saltwater with minor amounts of oil.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well is type well for the Lomvi and\r\nTeist formations.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 33/12-5 was spudded with\r\nthe semi-submersible installation Norskald on 9 October 1975 and drilled to TD\r\nat 4574 m in the Triassic Lomvi Formation. The well was drilled water based\r\nwith a lignosulphonate mud from 485 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe Tertiary and Late Cretaceous sections\r\nwere similar to other wells in the area, consisting predominantly of claystones\r\nand siltstones with minor sands. Along the southeast flank of the Statfjord\r\nfeature, erosion appears to have removed Jurassic sediments and a portion of\r\nthe Upper Triassic prior to draping of an indeterminate Jurassic sand,\r\ninterpreted as reworked Statfjord Formation sand, on the eroded Triassic\r\nsurface. Only minor shows were encountered in the reworked Jurassic sand, which\r\ntested saltwater on DS","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"114","properties":{"OBJECTID":114,"wlbNpdidWellbore":116,"wlbName":"2/7-14","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 2/7-14 was drilled to delineate the\r\nsouthern limits of the Ekofisk Field in the southern Norwegian North Sea. The\r\nprimary target was the Danian limestone. It was anticipated that the proposed\r\nlocation would have a similar structural position as development well 2/4-A-3\r\nand a comparable amount of Danian net pay. The secondary target was the Late\r\nCretaceous limestone, which was untested on the southern nose of the Ekofisk\r\nField.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eAppraisal well 2/7-14 was spudded with\r\nthe semi-submersible installation Haakon Magnus on 9 August 1979 and drilled to\r\nTD at 3390 m in Late Cretaceous limestone. The well was drilled with\r\nBentonite/Flosal spud mud to 20" casing point at 609 m, with\r\nSeawater/Native solids mud from 609 m to 13 3/8" casing point at 1526 m,\r\nwith Drispac/ Lignosulphonate dispersed, inhibitive mud from 1526 m to 9\r\n5/8" casing point at 3068 m, and with Bentonite/ Lignite/Drispac low fluid\r\nloss mud from 3068 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eTop Paleocene was encountered at 3045 m.\r\nTop of the Danian Limestone was penetrated at 3146 m, 15 m low to prognosis,\r\nwith 52 m of Danian net pay, compared to 86 m Danian net pay in well 2/4-A-3.\r\nThe Danian reservoir pressures were found to be less than virgin Ekofisk\r\npressures, evidence that the interval had been drained by the nearby well\r\n2/4-A-3. The Late Cretaceous was encountered at 3257 m, 13 m low to prognosis.\r\nThe section flowed oil with a large volume of associated water in DST 2. \u003c/p\u003e\r\n\r\n\u003cp\u003eA total of 119 m core was recovered in 13\r\ncores from the Paleocene and Late Cretaceous in the interval 3123 - 3306 m. No\r\nfluid sample was taken on wire line.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was suspended on 20 January 1980\r\nas an oil appraisal.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eFive drill stem tests were made through\r\nperforations in the 7" liner. \u003c/p\u003e\r\n\r\n\u003cp\u003eDST 1 at 3346.7 - 3349.8 m in the Late\r\nCretaceous Limestone recovered 12 m3 water cushion plus 21 m3 formation fluid\r\n(85% water,","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"115","properties":{"OBJECTID":115,"wlbNpdidWellbore":117,"wlbName":"2/8-3","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 2/8-3 is located in the Feda Graben,\r\nca 2 km north-east of the Valhall Field in the southern North Sea. The primary\r\nobjective was to test the Jurassic hydrocarbon potential. The secondary\r\nobjective was the chalk of the Shetland Group. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well is reference well for the Haugesund\r\nand Farsund Formations.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 2/8-3 was spudded with the jack-up\r\ninstallation Zapata Explorer on 16 June 1972 and drilled to TD at 4115 m in\r\nLate Jurassic shales of the Haugesund Formation. The well took 48 days to\r\ncomplete and was drilled with unical/lignosulphonate/caustic based mud.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eReservoir quality rock was absent\r\nthroughout the well. The first signs of oil were seen in Palaeocene tight siltstones\r\nwith poor porosities. These were described as bright gold yellow fluorescence\r\nwith a bright white streaming cut. Gas levels in the Shetland Group were low\r\nand no shows were seen in this group. A DST was run over part of this section\r\nbut yielded only drilling mud. From 3267.3 m, within the Early Cretaceous, gas\r\nlevels rose significantly and were associated with fair to poor shows in the\r\nMarls. The fluorescence was described as gold in colour with a slow pale yellow\r\ncut. From 3444 m, gas and shows increased and were contained in slightly\r\nargillaceous, hard limestone. Oil staining was seen and the fluorescence\r\ndescribed as dark yellow gold with a pale yellow to very light brown cut. Mandal\r\nFormation shale was the first Jurassic age rocks seen. Gas levels were very\r\nhigh through these shales and the shows were described as bituminous with no\r\ndirect fluorescence and a pale yellow cut. Between 3578 - 3600 m a gross\r\nsandstone unit was indicated by the gamma ray log. In rough","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"116","properties":{"OBJECTID":116,"wlbNpdidWellbore":118,"wlbName":"30/6-5","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 30/6-5 was drilled on the Brage\r\nHorst east of the Gullfaks fault block in the North Sea. The main purpose was\r\nto test the hydrocarbon potential in Middle Jurassic sandstone.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 30/6-5 was spudded with the\r\nsemi-submersible installation Deepsea Saga on 11 June 1981 and drilled to TD at\r\n3550 m in the Triassic Lunde Formation. No significant problem was encountered\r\nin the operations. The well was drilled with spud mud down to 951 m, with\r\ngypsum/polymer mud from 951 m to 1801 m, and with gel/lignosulphonate mud from\r\n1801 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe Brent Group, Tarbert Formation was\r\nencountered at 2824 m. From wire line logs and petrophysical analysis oil was\r\nfound from 2841 m down to 2899 m. Pressure measurements indicated oil/water\r\ncontact at 2907 m. Shows on cores continued down to 2933 m. The Etive Formation\r\nrepresented the main part of the net pay.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eEight cores were cut in the well. Cores 1\r\nand 2 were cut in the interval 2843.5 - 2854.7 m. Cores 3 to 8 were cut in the\r\ninterval 2871.5 - 2949.8 m. RFT oil samples were taken at 2847.5 m, 2867.1 m\r\n(film of oil), 2871.2 m (traces of oil), 2874.5 m, 2881 m, 2889 m, 2923 m (film\r\nof oil). The samples proved H2S contents in the range 30 - 50 ppm. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was permanently abandoned on 15\r\nAugust 1981 as an oil discovery.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eTesting\u003c/span\u003e\u003c/b\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe rig lacked qualified equipment and\r\npersonnel trained for drill stem testing with the levels of H2S proven by RFT\r\nsampling. Testing was therefore abandoned. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"117","properties":{"OBJECTID":117,"wlbNpdidWellbore":119,"wlbName":"33/12-6","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 33/12-6 was drilled on Tampen Spur in\r\nthe North Sea between the Gullfaks Sør Field area and the UK border. The\r\nobjective was to test a large structural feature in the southeastern part of\r\nBlock 33/12, located across a major regional fault bounding the eastern flank\r\nof the Brent and Statfjord Fields. The targets were sands in the Early and\r\nMiddle Jurassic sandstones of the Statfjord and Brent Groups.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 33/12-6 was spudded with the\r\nsemi-submersible installation Norskald on 2 March 1976 and drilled to TD at\r\n4612 m in the Triassic Hegre Group. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe Middle Jurassic Brent Group was\r\nencountered at 2973. Gross thickness was 312 meters. Only rare fluorescence\r\nwith minor gas readings were noted in the sands. Higher gas readings\r\nencountered were associated with coal beds. Using cutoffs of 40 percent clay\r\nvolume and 12.5 percent porosity, Schlumberger’s coriband analysis indicates\r\n103 meters of net sand with an average porosity of 20 percent. The coriband analysis\r\nshowed the sands to be water wet with only 6 m of net pay with water\r\nsaturations less than 65 percent, scattered throughout the unit. The Early Jurassic\r\nStatfjord Group sands were topped at 3721 meters. Gross thickness was 309.5\r\nmeters. Using the same cutoff parameters as for the Brent formation, log\r\nanalysis indicated 149 meters of net sand with an average porosity of 16\r\npercent and showed the sands to be water wet. Only 3 m of scattered thin zones\r\nhad water saturations less than 65 percent. No shows were seen in the samples.\r\nHowever, the core in the Statfjord sands had residual oil saturation over the\r\n6.51 meters recovered indicating earlier oil migration through the section.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe core w","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"118","properties":{"OBJECTID":118,"wlbNpdidWellbore":120,"wlbName":"7120/8-1","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 7120/8-1 is located in the\r\nSnøhvit Field area. It was designed to test possible hydrocarbon accumulations\r\nin a seismic closure (Alpha prime structure) located to the east of a major N-S\r\nrunning fault in the western part of the block. The primary target was\r\nsandstone of Middle Jurassic age.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 7120/8-1 was spudded with the\r\nsemi-submersible installation Ross Rig on 28 June 1981 and drilled to TD in\r\nLate Triassic rocks ((Fruholmen Formation). The 17 1/2" hole was drilled\r\nto 1128 m when the lower marine riser accidentally unlatched and two days of\r\nrig time were lost curing this problem before drilling could continue. When\r\nplugging back the well, gas bubbles were observed in the riser. Four days of\r\nrig time were lost before this problem was cured. Apart from this no\r\nsignificant difficulties were encountered and the well was drilled according to\r\nschedule. The well was drilled with spud mud down to 358 m, with gel mud from\r\n358 m to 750 m, and with gel/lignosulphonate mud from 750 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eRelatively dry gas was encountered at\r\n2092 m in sandstone of the Middle to Early Jurassic Stø Formation. Log\r\nanalysis, confirmed by RFT data, found a gas column down to a water contact at\r\n2180 m. The reservoir sandstone showed good to excellent reservoir properties.\r\nOrganic geochemical analyses showed TOC levels in the Early Cretaceous\r\nmudstones in the range ca 1.3 % to ca 5 %, generally increasing downwards to\r\nthe base of the Cretaceous. Within the Late Jurassic Hekkingen Formation shales\r\nTOC increases from ca 3 % to at the top (1990 m) to more than 9 % at the base.\r\nIn the Early Jurassic to Triassic below 2190 m occasional shales and thin coal\r\nbeds have good potential for gas and oil, but are restricted in volume. The sediments\r\nare immature for petroleum generation down to ca 2000 m and marginally mature\r\nfrom this depth to TD. Kerogen is generally of Type II, with some addition of\r\nType III in the lower","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"119","properties":{"OBJECTID":119,"wlbNpdidWellbore":121,"wlbName":"7119/12-1","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 7119/12-1 was the first exploration\r\nwell to be drilled in the Barents Sea. It was placed on a horst block forming\r\nthe upper part of the seismic closure 7119/12-1 Alpha structure. The well was\r\ndesigned to gather information about the hydrocarbon potential of the Troms I area, specifically to test hydrocarbon potential and reservoir rock quality of\r\n7119/12-Alpha. The primary target was sandstone of middle Jurassic age.\r\nSecondary targets were Early Jurassic and Late Triassic sandstones. Planned TD\r\nwas into rocks of probable Triassic age at an estimated depth of 3500 m.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 7119/12-1 was spudded with\r\nthe semi-submersible installation Ross Rig on 14 June 1980 and drilled to TD at\r\n3088 m in Early Jurassic Stø Formation. Two major problems were encountered in\r\nthe drilling phase of the well. The first one concerned boulders while drilling\r\n36" hole, causing low ROP and the hole caving in. The second problem was\r\nthe combination of junk in hole and a very hard, well-cemented sandstone at\r\n2654 m causing heavy bit wear. On 13 July drilling was interrupted by a 38 days\r\nstrike. Due to a late start-up and the strike, and as drilling season ended on\r\n1 October, no test could be performed. The well was drilled with spud mud down\r\nto 615 m and with bentonite / lignosulphonate mud from 615 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eTop reservoir, Stø Formation, came in at\r\n2658 m. Logs, RFT samples, and shows on cores and cuttings proved oil in the\r\nreservoir. The reservoir properties were however poor, with only 18,5 m net\r\nsand out of 430 m, and a moderate 13.6% average porosity in the net sand. Six\r\nRFT runs were conducted from 2658 m to TD. Out of a total of 73 pressure tests\r\nattempted only 15 pressure points were obtained due to tight formation. The pressure\r\ngradients obtained corresponded to 0.92 to 0.95 g/cc. Both logs and RFT showed\r\nthat the OWC had not been reached. Repeat Formation Test (RFT) segregated fluid\r\nsamples were collecte","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"120","properties":{"OBJECTID":120,"wlbNpdidWellbore":122,"wlbName":"7120/12-2","wlbHistory":"\r\n\r\n\r\n\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe primary objectives of well 7120/12-2\r\nwere to test sandstone reservoirs of Middle to Early Jurassic age in the\r\ncentral compartment of the Alke structure, and a deep seismic marker\r\ninterpreted to represent top of a possible carbonate reservoir of Permian age.\r\nA secondary objective was to test sandstones of Early Triassic age. The well\r\nwas planned to be drilled to 5000 m or into basement rocks to serve as the deep\r\ncommitment well on the licence.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 7120/12-2 was spudded with the\r\nsemi-submersible installation Treasure Seeker on 15 April 1981 and drilled to\r\nTD at 4680 m in basement rocks. After setting the 20" casing the kill line\r\noutlet flange was accidentally damaged and 5 days were spent repairing the BOP.\r\nThe well was drilled with bentonite/seawater mud down to 515 m and with\r\nlignosulphonate (Spersene / XP-20) mud from 515 m to TD. Severe problems were\r\nencountered with gumbo type clays during the interval from about 800 m to 1400\r\nm. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eA major fault was penetrated at 2410 m in\r\nthe well, faulting out approximately 400 m of the Triassic section. This is\r\nevident from comparing the Triassic sequences penetrated in the well 7120/12-1\r\nand 7120/12-2. Rocks of Permian age were encountered from 3657 m while\r\nmetamorphic basement was encountered at 4664 m. Hydrocarbon bearing sandstones\r\nwere encountered in the Middle to Late Jurassic and in the Middle to Late\r\nTriassic. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe "Alke Formation" from 1892\r\nm to 2314 m (Stø, Nordmela, Tubåen , and most of the Fruholmen Formation) was\r\nfound hydrocarbon bearing from 1888 m to the gas/water contact at 1981.5 m.\r\nThis interval consisted of relatively clean, fine to occasionally coarse\r\ngrained, homog","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"121","properties":{"OBJECTID":121,"wlbNpdidWellbore":123,"wlbName":"7120/12-1","wlbHistory":"\r\n\u003cp\u003eWell 7120/12-1 was, together with\r\nStatoil's well 7119/12-1, the first well to be drilled offshore northern Norway\r\nin the Norwegian Sea, Troms I area. Based on seismic interpretation and\r\nregional geological data the location of the well was planned to test possible\r\nsandstone reservoirs of Middle Jurassic, Early Jurassic, and Late Triassic age.\r\nPost-Jurassic sediments were not considered prospective due to lack of closure\r\nand/or reservoir rocks. The well was planned to be drilled through a seismic\r\nmarker at 1965 + 90 m and down to 2500 m (+ 300 m).\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eExploration well 7120/12-1 was spudded\r\nwith the semi-submersible installation Treasure Seeker on 1 June 1980 and\r\ndrilled to TD at 3573 m in Middle Triassic sandstones and shales (Kobbe\r\nFormation). When testing the BOP after setting the 20" casing a leakage\r\nwas detected in the kill line. Three days was spent repairing this before\r\noperations could continue. At 1900 m drilling was interrupted by a 35-days\r\nlabour strike, from 10 July to 14 August. The hole deviation was significant in\r\nthe 8 3/4" section, building angle from 4 deg at 1875 m to 23 deg at TD. This\r\nresulted in a 57 m difference between drilled depth and true vertical depth at\r\nfinal TD. The well was drilled with seawater and hi-vis pills through the\r\n36" and 26" sections down to 710 m and with lignosulphonate/lignite\r\n(Spersene/XP-20) mud from 710 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well encountered traces of\r\nhydrocarbons in thin sandstone reservoirs of Early Cretaceous and Late Triassic\r\nage.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe target seismic marker was reached at\r\n2019 m (the Fuglen Formation). A 450 m thick sequence of sandstones with minor\r\ninterbeds of shales of Middle to Lower Jurassic and Late Triassic age was\r\npenetrated below this marker, from 2047 m to 2497 m (Stø, Nordmela, Tubåen, and\r\nFruholmen Formations). The sandstones in this sequence were water bearing. From\r\nlog evaluation total net sand in the sequence was 271.5 m with an average\r\nporosi","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"122","properties":{"OBJECTID":122,"wlbNpdidWellbore":124,"wlbName":"2/8-1","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 2/8-1 was the eighth, and at the\r\ntime the most southerly exploration well to be drilled in Norwegian waters. The\r\ngeological objective of the well, in this early stage of exploration, was to\r\ntest all horizons down to the Permian Rotliegendes Group. The well also had as\r\na technical objective to test the use of a large, single hull vessel for\r\ndrilling in the North Sea.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 2/8-1 was spudded with the vessel\r\n"Drillship" on 28 November 1967. This was the first drilling\r\noperation in Norwegian waters in which a vessel was used. Many problems arose\r\nduring the drilling of 2/8-1. Repeated failures of the anchor mooring chains at\r\ntensions loads of only 10?50 % of their rated breaking occurred. To this, the\r\nweather conditions in the North Sea turned out to be more severe than had been\r\npredicted. Several storms in the 25 to 30 year category were encountered, and\r\nin January a storm that would be expected once every 75?100 years occurred with\r\nmaximum waves of 15 - 17 m. After this storm the Drillship was in shipyard for\r\nrepairs and modifications from 19 January to 8 March 1968. Even so, these\r\nfailures of anchor chains eventually resulted in failure of the BOP stack and\r\n13 3/8" well head after having drilled to 2595 m, and made clear that\r\ndrilling could not continue safely. \u003c/p\u003e\r\n\r\n\u003cp\u003eBesides the mooring problems, other\r\ndifficulties occurred. While testing in the 12 1/4" hole, the Drill Stem\r\nTest (DST) - tool dropped into the hole. The hole was reamed and the fish\r\nretrieved. The drill pipe stuck twice when making trips, first at 2118 m. The\r\npipe was not recovered and a fish was left from 2007 - 2118 m. A cement plug\r\nwas set and the hole side tracked. The pipe stuck again at 2237 m and a new\r\nfish was left from 2052 to 2237 m. Two cement plugs were set, one in the 13\r\n3/8" casing shoe and one in the casing from 140 m to sea floor. This\r\noccurred in connection with the BOP and wellhead break, and th","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"123","properties":{"OBJECTID":123,"wlbNpdidWellbore":125,"wlbName":"33/9-3","wlbHistory":"\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 33/9-3 was drilled on the Statfjord\r\nstructure on Tampen Spur in the northern North Sea, as a replacement well for\r\nthe junk well 33/9-2. The primary objective was to provide seismic velocity\r\ncontrol for detailed field mapping and to provide additional reservoir data for\r\nthe Statfjord Field development.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 33/9-3 was spudded with the semi-submersible\r\ninstallation Norskald on 15 September 1974 and drilled to TD at 2992 m in Late\r\nTriassic sediments of the Statfjord Group.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe target reservoir Brent Group was\r\nencountered at 2411 m. It contained oil all through down to top Dunlin Group at\r\n2599 m. The base of the reservoir was encountered above the oil water contact.\r\nThe reservoir quality was excellent with average measured core porosity of 29%\r\nand measured permeabilities up to 7.7 Darcy.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eA total of 152 m core was recovered in 13\r\ncores from the interval 2422.9 m to 2622.2 m in the reservoir section. Total\r\ncore recovery was 76.1%. Six FIT fluid samples were taken at 2419 m (35.4 °API\r\noil and mud filtrate), 2455 m (38.4 °API oil and mud filtrate), 2422 m (36.4\r\n°API oil, gas and mud), 2423 m (36.6 °API oil and gas), 2534 m (35.6 °API oil\r\nand mud filtrate), and 2595 m (water, mud filtrate and trace oil). \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was permanently abandoned on 14\r\nNovember as an oil appraisal well.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eTesting\u003c/span\u003e\u003c/b\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eA DST over the interval 2479 to 2481 m did\r\nnot produce fluids due to tool failure. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"124","properties":{"OBJECTID":124,"wlbNpdidWellbore":126,"wlbName":"33/12-4","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 33/12-3 was drilled on the Statfjord\r\nstructure in the Tampen Spur area. It was designed to test the erosional\r\nescarpment on the east flank of the structure for possible trapping of\r\nhydrocarbons in an area downfaulted to the Statfjord Field pay section to the\r\nwest. Primary objectives of the well were the Early Jurassic Statfjord Group\r\nsands and possible Middle Jurassic Brent Formation sands. Well 33/12-3 was\r\njunked due to technical problems. The rig was moved 30 m and re-spudded as\r\nreplacement well 33/12-4.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 33/12-4 was spudded with\r\nthe semi-submersible installation Nordskald on 17 May and drilled to 2896 m in Late\r\nTriassic sediments in the Statfjord Group. The well was drilled with seawater\r\ndown to 495 m and with water based lignosulphonate mud from 495 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe Middle Jurassic Brent Group was\r\nencountered at 2675 m, ca 55 m high to prognosis but, as anticipated, well\r\nbelow the Brent oil/water contact of 2609 m (2584 m MSL) in the upthrown block\r\nof the field. Scattered poor to fair hydrocarbon indications were noted in the\r\ncores but gas readings were low. Average core porosity in the sands is 23 %,\r\nranging from two to 29 %. Measured horizontal permeabilities average 604 mD and\r\nrange between 0.01 and 2028 mD. The CPI log indicated some 40 feet of\r\nprospective net pay with 23 percent average porosity and 53 percent average\r\nwater saturation.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-US\u003eThe top of the Statfjord Group was\r\npenetrated at 2757 m, only 2 m low to prognosis. Core 4 at the top of Statfjord\r\nrecovered sand, siltstones and claystones with no shows. However, poor shows\r\nwere recorded above and below the cored section. Using\u00A0 a 65% water saturation\r\ncut-off Schlumberger's pre","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"125","properties":{"OBJECTID":125,"wlbNpdidWellbore":127,"wlbName":"31/6-6","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 31/6-6 was drilled in the Troll East\r\ngas province. It was designed to test possible gas accumulations in the Late to\r\nMiddle Jurassic sandstones and to test the quality of a reservoir siltstone in\r\nthe Heather Formation.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 31/6-6 was spudded with the\r\nsemi-submersible installation Deepsea Bergen on 22 May 1984 and drilled to TD\r\n2293 m in the Late Triassic Hegre Group. No significant problem was encountered\r\nin the operations. The well was drilled with spud mud down to 716 m, with\r\nKCl/polymer mud from 716 m to 1771.5 m, and with pre-hydrated bentonite/CMC mud\r\nfrom 1771.5 m to TD. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe well encountered gas from top Heather\r\nreservoir at 1516 m to a GWC at 1568.5 m, 7.5 m into the Sognefjord Formation.\r\nNo oil shows were reported from the well. Nine conventional cores were cut in\r\nthe interval 1525 m to 1771.5 m in the Middle to Late Jurassic. FMT samples\r\nwere taken at 1571.8 m and 1576.5 m in the Sognefjord Formation. Both contained\r\nformation water and mud filtrate.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was completed on 29 July 1984 as\r\na gas appraisal.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eTwo drill stem tests were performed in\r\nthe well. DST 1A tested 1562 m to 1567.5 m in the Sognefjord Formation\r\nsandstone. It produced maximum 779 x 10 Sm3 gas /day on a 64/64" choke. DST\r\n2 from 1523 m to 1536 m in the Heather Formation siltstone showed a very low\r\nproduction rate, 10.7 x 10 Sm3/day. The reservoir temperature was 62.5 deg. C\r\nin DST 1A and 58 deg. C in DST 2.\u003c/p\u003e\r\n\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"126","properties":{"OBJECTID":126,"wlbNpdidWellbore":128,"wlbName":"35/11-1","wlbHistory":"\r\n\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 35/11-1 was drilled on the\r\n"A" structure close to the border between Block 35/11 and Block\r\n35/12, and ca 25 km north of the Troll Field. Its primary objective was to\r\nassess the hydrocarbon potential in Middle to Upper Jurassic strata on the\r\n"A" structure that straddles the border between Block 35/11 and the\r\nunlicensed Block 35/12. Sands of Lower Jurassic age were regarded as secondary\r\nobjectives. Planned TD was into the Triassic.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eA total of 317 pockmarks were identified\r\nin the area from the site survey. The average density was estimated to 20 per\r\nsquare kilometre. The average depth of these was 1-2 m, though some were of\r\ngreater depth. None of the pockmarks were seen to be active.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 35/11-1 was spudded with the\r\nsemi-submersible installation on 23 May 1984 and drilled to TD at 3361 m,\r\napproximately 100 meters into in the Triassic Hegre Group. The 36" hole\r\nsection was drilled through boulder beds causing the bit to build angle. Because\r\nof high deviation the well was re-spudded. After drilling the 26" hole,\r\nthe well flowed several times. Although the well would not stay static, it was\r\ndecided to run the 20" casing in an attempt to seal off the water flow.\r\nThis resulted in the 20" casing parting at the wellhead, but was\r\nsuccessfully recovered. After reaming some tight spots the 20" casing was\r\nset and cement was squeezed to seabed to stop the water flow in annulus. Some\r\ntight spots were experienced in the 17 1/2" and 12 1/4" hole\r\nsections. Lost circulation occurred at 2439 m, due to this the 9 5/8"\r\ncasing was run. The well was drilled with gelled seawater spotted with hi-vis\r\npills down to 1015 m and with KCl/polymer mud fr","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"127","properties":{"OBJECTID":127,"wlbNpdidWellbore":129,"wlbName":"2/3-4","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 2/3-4 was drilled by Gulf Oil\r\nCorporation - Norway Branch as a non-obligatory well on behalf of the\r\nparticipants in Production Licence 022. All obligatory work had been previously\r\nbeen done. The well is situated 275 km SSW of Stavanger. Geologically, the\r\nlocation was chosen on the "Ula Trend" on the NE flank of the Central\r\nGraben in the southern Norwegian North Sea. The principal objective of the well\r\nwas to test structural closure of Upper Jurassic Ula Formation sandstone. This\r\nformation was believed to exist within 100 m below the nearest representative\r\nmappable seismic reflection, the Base Cretaceous Unconformity. The well was\r\nalso planned to penetrate an Oligocene sand down-dip from a very small gas\r\naccumulation defined by a seismic flat spot anomaly, and which was therefore\r\nbelieved to be water wet at the location. The chalk reservoir was not predicted\r\nto be hydrocarbon bearing, nor was the well located within its mapped closure.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eExploration well 2/3-4 was spudded with\r\nthe jack-up installation Glomar Moray Firth I on 28 may 1984 and drilled to a\r\ntotal depth of 3386.3 m in Permian (Zechstein) evaporites. The well was drilled\r\nwith seawater and gel down to 651 m and with Safemul oil based mud from 651 m to\r\nTD. Some swelling of the Miocene clay occurred during drilling of the 17\r\n1/2" hole, otherwise no major problems occurred. Well 2/3-4 was the first\r\nexploration well for which NPD approved that conventional wire line logs was\r\nreplaced with a suite of MWD logs.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe primary objective, Ula Formation\r\nsands, was penetrated at 3006 m and was 207 m thick. The porosity of\r\nparticularly the uppermost 170 m was excellent, generally between 25% and 30%.\r\nElectric logs, and a formation fluid sample (from FMT), indicated that the\r\nreservoir was water bearing throughout. Shows detection was made difficult due\r\nto the mud used. However, spectrofluorometric analyses on cuttings samples\r\nwhile drilli","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"128","properties":{"OBJECTID":128,"wlbNpdidWellbore":130,"wlbName":"7121/7-1","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 7121/7-1 was drilled in order to\r\ntest the Lower/Middle Jurassic sandstone on the eastern part of the Albatross\r\nstructure on Tromsøflaket. The primary target was defined as sandstone\r\nintervals in Early-Middle Jurassic and Late Triassic.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 7121/7-1 was spudded with\r\nthe semi-submersible installation West Vanguard on 11 June 1984 and drilled to\r\nTD at 2160 m in the Late Triassic Fruholmen Formation. No significant problems\r\nwere encountered during drilling. The well was drilled with spud mud down to\r\n764 m and with a gypsum/polymer mud from 764 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eLogs, RFT pressure gradients, and cores\r\nindicated gas in the Lower/Middle Jurassic sandstone (Stø Formation)\r\nencountered at a depth of 1849 m. Gas/water contact was evaluated to 1902.5 m\r\nRKB, the same as found in well 7120/9-1, also drilled on the Albatross\r\nstructure. From the GWC down to TD in the well shows were observed in\r\nsandstones on cores and cuttings. Four cores were cut in the interval 1851 m to\r\n1935 m in the Stø Formation. Two segregated samples were taken, at 1900.2 m and\r\nat 1851.0 m. The 2-3/4 gallon chamber from 1900.2 m was bled off offshore and\r\ngave an opening pressure at 2220 psig.\u00A0The sample contained 58.25 cuft of gas\r\nand 1 litre of liquid consisting of 800 cc water/mud filtrate and 200 cc\r\ncondensate. The 2 3/4 gallon chamber from 1850.5 m contained 2200 psig with\r\n4500 cc water based liquid, a small volume condensate, and 41 cuft of gas. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 5\r\nAugust 1984 as a gas appraisal well. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eTwo DST were performed, one water test\r\nover the interval 1947.2 m to 1960.18 m and one gas test over the interval 1867\r\nm to 1872 m. The recorded temperatures were in agreement with those observed in\r\nwell 7120/9-1. The reservoir fluids had the same composition in well 7121/7-1\r\nas in well 7120/9-1. The sandstone in the tested water zone had good reservoir\r\nproperties. The","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"129","properties":{"OBJECTID":129,"wlbNpdidWellbore":131,"wlbName":"25/2-8","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThe appraisal well 25/2-8 was drilled on\r\nthe East Frigg Field. The main objectives of the well were to obtain a better\r\nestimation of the gas reserves on East Frigg and good pressure data in both the\r\nFrigg sand and the Paleocene sand. To achieve better knowledge about the\r\npetrophysical characteristics of the different reservoirs, it was decided to\r\ncore the Frigg sand, the shaly member, the tuff zone and the Paleocene sand.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was spudded with the drill ship\r\nLe Pelerin on 18 June 1984 and drilled to TD at 2380 m in the Lower Paleocene\r\nLista Formation. Problems due to tight hole occurred in the 12 1/4" hole\r\nsection. The pipe got stuck at 1397 m, but was worked free. Problems pressure\r\ntesting the BOP occurred with hole depth at 1745 m. A cement plug was set from\r\n1000 m to 890 m due to the BOP problems. The core barrel was lost in the hole\r\nwhen pulling out of the hole with core no 9. The fish was recovered. The well\r\nwas drilled using a water-based mud. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe Frigg sand was reached as prognosed\r\nat 1917.5 m. This formation is 283 m thick with a 48.5 m hydrocarbon bearing\r\ncolumn: gas from 1917.5 m to 1957 m and oil from 1957 to 1966 m. Below this\r\nlevel was 18 m of residual oil. Shows were detected on cores and cuttings down\r\nto 2040 m. Balder formation (Paleocene) was reached at 2201 m with several\r\nIntra Balder Formation Sandstones. RFT pressure measurements in the Frigg sand\r\nand Intra Balder Formation Sandstone indicated that there is no direct fluid\r\ncommunication between the two formations. RFT segregated fluid samples were\r\nrecovered from 2259 m in Intra Balder Formation Sandstone and at 1956.7 m and\r\n1993 m in the Frigg Formation. The Intra Balder Formation Sandstone sample and\r\nthe deeper Frigg sample recovered only water and mud filtrate and no gas, while\r\nthe upper Frigg Sample recovered mud filtrate with traces of oil and about one\r\nlitre of gas. Nine cores were cut, seven in the Eocene and two in","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"130","properties":{"OBJECTID":130,"wlbNpdidWellbore":132,"wlbName":"7119/9-1","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eExploration well 7119/9-1 is located on\r\nthe Ringvassøy ? Loppa Fault Complex west of the Snøhvit Field area. The well\r\nwas designed to test a narrow horst, elongated in a NE-SW direction. The horst\r\nbrings the main prospect, the Middle to Lower Jurassic Sandstones up to a depth\r\nof about 2700 m, in a position surrounded with Cretaceous Shale. The well is\r\nlocated close to the top of the horst. This target was found gas bearing in the\r\ntwo nearest wells: 7119/12-3 to the south, located in the same structural\r\ntrend, and 7120/7-1, located higher up toward the Hammerfest Basin to the\r\nsouth-east.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was spudded with the\r\nsemi-submersible installation Byford Dolphin on 28 June 1984 and drilled to TD\r\nat 3248 m in Late Triassic rocks. The well took a kick at 2744 m where a pit\r\ngain of 2 m3 was observed. Some technical problems occurred on the rig during a\r\nwiper trip before final logging of the 8 1/2" hole. During logging of the\r\nsame sequence the RFT tool got stuck twice but was recovered in both cases. The\r\nwell was drilled using water-based mud. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe well drilled through mainly claystone\r\nand shale formations down to top Jurassic at 2702 m. The lower Cretaceous\r\nKolmule Formation was found silty and sandy between 2400 m and 2450 m. Top\r\nJurassic Hekkingen Formation was penetrated at 2702 m and contained two good\r\nreservoir sections, a Middle ? Early reservoir and a deeper Pliensbachian\r\nreservoir. Above the upper reservoir zone 46 m of Late Jurassic shale was\r\ndrilled. This sequence consisted of an upper Volgian ? Kimmeridgian sequence\r\nand a lower Oxfordian-Callovian shale sequence separated by an Oxfordian\r\nunconformity near 2719 m (more accurate depth cannot be proven due to logging\r\nproblems in this section of the well). The upper Jurassic sandstone reservoir (Stø\r\nFormation) was penetrated at 2748 meters. The reservoir was well developed with\r\na 120 meter gross thickness. The two cores cut near the top of t","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"131","properties":{"OBJECTID":131,"wlbNpdidWellbore":133,"wlbName":"6407/9-1","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 6407/9-1 was drilled in the Froan Basin offshore Mid Norway. The primary objective of the well was evaluation of\r\npossible reservoirs of Early to Middle Jurassic age. Secondary objectives were\r\nevaluation of deeper reservoirs of Early Jurassic to Upper Triassic age. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe well is Type Well for the Rogn\r\nFormation. It is Reference well for the Viking Group and Spekk Formation\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 6407/9-1 was spudded with\r\nthe semi-submersible installation Borgny Dolphin on 26 June 1984 and drilled to\r\nTD at 2500 m in the Late Triassic Red Beds. Due to high deviation in the\r\n36" hole section, the well was re-spudded. Junk was fished out of the hole\r\nbefore and after performing a leak off test below the 20" casing shoe. Gas\r\nbubbles were observed around the BOP stack, the 20" casing was perforated\r\nand several cement squeeze jobs were performed. The 13 3/8" casing was run\r\njust below the 20" casing. Some technical problems occurred while drilling\r\nthe 12 1/4" hole. Some tight spots occurred in the two lowermost hole\r\nsections. The bottom hole assembly got stuck at 2027 m, but was successfully\r\nfreed. The well was drilled with seawater and bentonite down to 809 m and with\r\nKCl/Polymer mud from 809 m to TD. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe well encountered a Late Jurassic\r\nintra-Spekk Formation sandstone unit which was previously unknown in the\r\nHaltenbanken area. It has later formally been named the Rogn Formation. It was\r\noil filled from the top at 1621 m down to an OWC at 1660 m. Tests showed light\r\noil with a low content of gas and condensate. The underlying reservoir\r\nsandstones of Middle/Early Jurassic to Late Triassic age were all water\r\nbearing, nor were oil shows reported in any other porous section in the well.\r\nFive cores were cut from the Late Jurassic into the Middle Jurassic. The three\r\nfirst were cut in the Rogn Formation while the two last recovered an underlying\r\nSpekk sequence and upper part of th","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"132","properties":{"OBJECTID":132,"wlbNpdidWellbore":134,"wlbName":"16/7-5","wlbHistory":"\r\n\r\n\u003cp\u003eWell 16/7-5 is located ca 10 km east of\r\nthe Sleipner Øst field in the North Sea. The primary objective was to test\r\npotential gas bearing Jurassic/Triassic sandstones. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 16/7-5 was spudded with the\r\nsemi-submersible installation Zapata Ugland on 2 July 1984 and drilled to TD at\r\n2900 m in the Triassic Smith Bank Formation. Due to turning of the permanent\r\nguide base the 30" casing had to be re-landed. No other major problems\r\noccurred during drilling. The well was drilled with gel/sea water down to 170\r\nm, and with seawater/lignosulphonate gel from 470 m to TD. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe ?Jurassic/Triassic (Skagerrak\r\nFormation) was encountered at 2594, underlying an interpreted one-meter layer\r\nof Draupne shale. A 306 m gross / 120.5 m net (22% average porosity) sequence\r\nof sands was penetrated. No significant hydrocarbon shows were encountered\r\nwhile drilling the well. Electric log analysis also confirmed that the\r\nJurassic/Triassic Sandstone (primary objective) was water bearing. RFT pressure\r\nmeasurements and samples suggested the possible presence of minor amount of gas\r\nin the upper part (2594 m to 2642.6 m) where the pressure gradient was lower\r\nthan the water gradient (below 2662.5 m). However, the pressure readings were\r\nscattered in this interval and very much subject to interpretation.\u003c/p\u003e\r\n\r\n\u003cp\u003eOne core was cut from 2590 to 2603 m (2596\r\n- 2612.5 m logger's depth) in the top of the target sands in the Skagerrak\r\nFormation. Three successful RFT fluid samples were taken. The first sample, at\r\n2691 m, recovered "2800 cc. of light brown fluid, mainly mud filtrate and\r\nmud, no gas, no fluorescence". The second, at 2806.5 m, recovered "8600\r\ncc. of clear medium brown fluid, mainly mud filtrate with a few cc's of gas.\r\nThe fluid had no odour or taste but it had a very pale bluish white\r\nfluorescence". The third, at 2603 m, recovered "8700 cc. of none\r\nclear (turbid) fluid + few cc's of gas. The fluid had no odour or tast","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"133","properties":{"OBJECTID":133,"wlbNpdidWellbore":135,"wlbName":"7121/4-1","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eExploration well 7121/4-1 was drilled in\r\nthe Hammerfest Basin in the Troms I area. The primary objective was to test\r\npossible hydrocarbon accumulations in sandstones of Middle to Early Jurassic\r\nage. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 7121/4-1 was spudded with the\r\nsemi-submersible rig West Vanguard on 6 August 1984 and drilled to TD at 2609 m\r\nin Late Triassic sediments (Fruholmen Formation). Loss of circulation occurred\r\nat TD in 12 1/4" section at 2285 m, and several times during drilling of 8\r\n1/2" hole but otherwise operations went without significant problems. The\r\nwell was drilled with spud mud down to 817 m, with gypsum/Celpol from 817 m to\r\n2285 m, and with gel/chromium-lignosulphonate from 2285 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eHydrocarbon accumulations were discovered\r\nin two separated sandstone sequences. The uppermost sequence between 2318 m and\r\n2442 m in the Stø and Nordmela formations contained gas over oil,\r\nwhile the lower sequence was gas bearing between 2468.5 m and 2473 m in the\r\nuppermost few meters of the Tubåen Formation. The gas/oil contact in the\r\nupper reservoir was seen from RFT to be at 2425. The oil zone, 2425 m to 2442 m\r\nin the Nordmela Formation, consists of an interbedded sandstone/shale sequence\r\nwith fair/poor reservoir properties. There is a sealing shale between 2444 and\r\n2468.5 m that screens off the upper gas-oil system from the lower Tubåen gas\r\nreservoir. The lower gas zone has good reservoir properties. The sandstone\r\ncontinues to TD at 2587 m, interrupted by some minor shale beds and one major\r\nshale bed at 2532 m to 2560 m. Four cores were cut in the reservoir interval\r\nfrom 2321 m to 2416.35 m in the Middle Jurassic down into the Early Jurassic.\r\nThree segregated RFT samples were taken. For all three samples the 2 3/4 gallon\r\nchambers were bled off at well site. Sample 1 from 2365 m recovered gas, black\r\ncondensate, and mud filtrate. Sample 2 from 2470 m recovered gas, brown\r\ncondensate, and mud filtrate. Sample 3 from","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"134","properties":{"OBJECTID":134,"wlbNpdidWellbore":136,"wlbName":"35/3-2","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWhereas Saga Petroleum operated license\r\n041, BP operated wildcat well 35/3-2 under license 041 by special agreement.\r\nThe well was the second well drilled on this block, 35/3-1 was abandoned in the\r\nMiddle Jurassic due to high calculated pore pressures. Well 35/3-2 was drilled\r\non a westerly dipping fault block. The primary target of the well was Early\r\nJurassic sandstone, secondary targets were any other Jurassic sandstones\r\nencountered.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 35/3-2 was spudded with the\r\nsemi-submersible installation Sedco 707 on 19 May 1980 and drilled to TD at\r\n4400 m in ?Caledonian age basement rocks. The well was drilled with seawater\r\nand gel down to 902 m, with gypsum/CMC mud from 902 m to 2305 m, with Poly\r\nRX/Drispac from 2305 m to 3833m, and with Poly RX/Lignosulfonate mud from 3833\r\nm to TD. The well started to flow while drilling the 24" hole.\u00A0 Heavy mud\r\nwas pumped down the hole, but there was very little difference between the\r\nfracture gradient and the bottom hole pressure and returns were lost several\r\ntimes. A loss/gain situation was maintained until the casing setting depth was\r\nreached. When running the 18 5/8" casing the string parted and 22 joints\r\nwere left in the hole.\u00A0 The string was recovered successfully, and a new string\r\nwas run and cemented without problems.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well penetrated strata from Tertiary\r\nthrough Jurassic and Triassic before reaching basement. Hydrocarbon shows were\r\nencountered in Lower Cretaceous and Lower Jurassic sands. The primary target\r\nJurassic sandstones were found to be very tight, and no DST was carried out in\r\nthese. In stead two zones in the Lower Cretaceous Sandstone were tested,\r\nproducing water and gas/condensate respectively. The lower Cretaceous sands are\r\ninterpreted as submarine fan deposits. The Lower Jurassic coarsening upward\r\nsequences may represent offshore open marine bars cut by tidal channel deposits\r\nand capped by a transgressive marine sheet sand. Log ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"135","properties":{"OBJECTID":135,"wlbNpdidWellbore":137,"wlbName":"2/1-7","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 2/1-7 was drilled on a\r\nstructure in the centre of the block. The primary target was Rothliegendes\r\nsandstone in a large fault bounded structure mapped at base Zechstein Group\r\nlevel. A secondary objective was Late Jurassic Ula Formation sandstone in an\r\nextension of the 2/1-3 Gyda discovery. In the 2/1-3 well two sequences of Ula\r\nFormation sandstone had been encountered, and the upper of the two had been\r\noil-bearing\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 2/1-7 was spudded with the\r\n3-leg jack installation Glomar Moray Firth 1 on 6 September 1984 and drilled\r\nto TD at 5464 m in the Permian Rotliegendes Group. Pumping lost circulation\r\nmaterial, without changing the mud weight, stopped loss of mud at 1710 m. Top\r\nchalk came in at 3190 m. This whole sequence was drilled with turbine. At 3746\r\nm the drill string got stuck, and the tight interval was located between\r\n2600-2900 m. The string was freed by circulating acidic mud. Full circulation\r\nwas maintained during this whole operation. While pulling out to change bit at\r\n5077 m the drill string was lost in the hole. At the same time 170 bbls of mud\r\nwas lost. One reason for this mud loss could be the "piston effect"\r\ncaused by the drill string falling down the hole. The pipe was fished out piece\r\nby piece, and the stabilisers above the bit were milled out. At 5081 m the\r\ndrill string was screwed off 300 m above the bit. Fishing was successful and\r\ndrilling continued. Drilling was stopped at 5113 a to perform pressure test.\r\nDuring this operation, before reliable results were obtained, the RFT-tool got\r\nstuck in the hole. After extensive fishing the operator decided to plug back\r\nand sidetrack the hole. The technical sidetrack was kicked off at 5092 m, and\r\ndrilled to 5119 m. Problems at this depth made another sidetrack necessary, and\r\nthe hole was plugged back to 4747 m. The new sidetrack was kicked off from 5080\r\nm and dri1led to a TD of 5464 m, which made this hole 4 m short of being th","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"136","properties":{"OBJECTID":136,"wlbNpdidWellbore":138,"wlbName":"6507/7-1","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eLicense 095 was awarded to the\r\nConoco/Statoil/Arco/Tenneco group in 1984 with Conoco as operator. The area,\r\nknown as Haltenbanken, is a promising oil and gas province. It straddles two\r\nmajor Mesozoic structural features, the Trøndelag Platform and the Vøring Basin\r\nand lies along the western flank of the series of NNE-SSW faults, which\r\nseparate them. The well was drilled on the A-prospect and was designed to test\r\na major fault block. It was hoped to test oil bearing Middle Jurassic\r\nSandstone at approximately 3898 m with a secondary objective at the Early\r\nJurassic level.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well is Type Well for the Lysing\r\nFormation.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 6507/7-1 was spudded with\r\nthe semi-submersible drilling rig Nortrym on 10 August 1984 and drilled to TD\r\nat a depth of 4825 in the Early Jurassic Tilje Formation. The well was drilled\r\nwith seawater and hi-vis pills down to 906 m, with gypsum/polymer mud from 906\r\nm to 3803 m, and with gypsum/lignite mud from 3803 m to TD. Few problems were\r\nexperienced whilst drilling the well. Some time was lost due to\r\ngumbo-associated problems. Mud was lost to formation while cementing the 13\r\n3/8" casing, resulting in the top of cement being lower than planned.\r\nHowever this did not affect the strength at the shoe, as it was possible to\r\nmake a good leak off test after drilling out. Tight hole problems were\r\nexperienced on a bit trip from 3716 meters, with over pull recorded on the\r\nmajority of subsequent trips. In addition a gain of 45 bbls of mud at 4360\r\nmeters indicated apparent under balanced conditions. Mud weight was\r\nprogressively raised from 11.2 ppg at 4081 meters to 12.6 ppg by 4360 meters in\r\nresponse to this problem. A further increase to 13.1 ppg was made at TD due to\r\nlogging difficulties associated with tight hole. The overall operation took 115\r\ndays from spud. Total depth was reached in 87 days, while an additional 28 days\r\nwere used to log, test and abandon the well. \u003c/p\u003e\r\n\r\n\u003cp\u003e","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"137","properties":{"OBJECTID":137,"wlbNpdidWellbore":140,"wlbName":"34/10-9","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 34/10-9 was drilled on the central\r\npart of the Gullfaks Field. The primary objective was to test sandstones of the\r\nEarly Jurassic Cook Formation. Originally the well was planned to be drilled to\r\na total depth of 2000 m. Results from the well required further drilling into\r\nsandstones of the Statfjord Formation.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 34/10-9 was spudded with\r\nthe semi-submersible installation Ross Rig on 24 March 1980 and drilled to TD\r\nat 2200 m in the Early Jurassic Burton Formation. As in other wells drilled in\r\nthe area the pore pressure was close to the formation integrity in the pressure\r\ntransition zone. Lost circulation combined with high gas readings, was\r\nexperienced on several occasions in this zone between ca 1730 and 1760 m. Apart\r\nfrom that, the drilling was carried out without any specific problems. The well\r\nwas drilled with seawater and high viscosity slugs down to 845 m, and with a\r\ngel/lignosulphonate mud system from 845 m to TD. From the well site sample\r\ndescription diesel was added to the mud in the interval 1260 to 1350 m.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe Brent Group, Ness formation was\r\nencountered at 1833 m, directly underlying the Late Cretaceous Kyrre Formation.\r\nThe Brent Group was hydrocarbon bearing down to base Rannoch Formation at 1945\r\nm with ca 97 m net hydrocarbon bearing sands. The Cook Formation was\r\nhydrocarbon bearing with an oil/water contact at 2118 m. First trace of oil\r\nshows, fluorescence, was seen at 1220 m. Weak shows on claystone and limestone\r\nwere recorded from this depth to 1500 m. Stronger oil shows with "oil\r\nstreaks over shaker" and oil-smell were recorded from 1690 m to 1720 m in\r\nthe Lista Formation. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eFour cores were cut in the well. Cor","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"138","properties":{"OBJECTID":138,"wlbNpdidWellbore":141,"wlbName":"31/6-7","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eAppraisal well 31/6-7 was drilled in the\r\nsouth-west corner of the Troll East gas province. The main objectives of the\r\nwell was to determine the lateral extent of the reservoir, to determine the\r\nfluid contacts in the Sognefjord Formation and to obtain the best possible\r\nseismic correlation within the reservoir from well 31/6-1. If hydrocarbons were\r\nencountered the well would be tested to obtain a number of reservoir\r\nengineering parameters: permeabilities and skin, fluid samples, pressure/temperature\r\ndrops in tubing at various flow rates, reservoir inflow at high flow rates, and\r\nbehaviour of gravel pack at high rates.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 31/6-7 was spudded with the\r\nsemi-submersible installation Treasure Seeker on 1 April 1985 and drilled to TD\r\nat 698 m in Oligocene sediments. After drilling the 26" hole to 694 m, and\r\nsetting the 20" casing it was discovered that the angle of the 18\r\n3/8" wellhead was 2.5 degrees and it was decided to junk the well. The\r\nwell was permanently plugged and abandoned on 13 April 1985, and the rig was\r\nmoved 50 m due north to spud replacement well 31/6-8.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was performed\u003c/p\u003e\r\n\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"139","properties":{"OBJECTID":139,"wlbNpdidWellbore":142,"wlbName":"8/3-1","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 8/3-1 was the first\r\nexploration well to be drilled in Norwegian waters. The chosen location was\r\nnorthwestern part of the Danish Norwegian. The well was proposed to investigate\r\nthe largely unknown stratigraphic sequence and lithologies in a virgin area on\r\nan attractive, representative seismic structure. Although the seismic feature\r\nwas based on low-density reconnaissance control, the structure qualified for\r\ntesting in terms of vertical and areal closure and inferred thickness of\r\nsediments. The well site location was thought to lie on the east flank of the\r\nTertiary "Viking" basin, but on the west flank of a Mesozoic sub\r\nbasin. The position and delineation of older basins was uncertain, although\r\nPermian? salts of sufficient thickness to flow were recognized as probably\r\npresent at depth. Interpretation of data from a seismic grid with about 7 Km\r\nline spacing indicated a regionally high, west-dipping, normally faulted block\r\nto be present. The well location was sited near the crest of the highest step\r\nfaulted block. A diapiric Zechstein? salt plug was interpreted to be present,\r\nto the east on the down side of the principal fault block. The salt could have\r\npartially intruded along the fault plane, up through the Kimmerian horizon."\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 8/3-1 was spudded with the\r\nsemi-submersible installation Ocean Traveller on 19 July 1966 and drilled to TD\r\nat 3015 m in Caledonian schists. While pulling out of the hole to pick up a\r\ncore barrel at a depth of 296I m the pipe stuck at 1660 m, and was pumped free\r\nwith seawater. The hole began caving immediately. Extensive caving over the\r\ninterval 1320 m to 2030 m lead to bridging, stuck pipe, and logging problems.\r\nEighteen rig-days were spent to cure the problems by reaming and raising the\r\nmud weight and to log the section in various logging attempts. The hole was\r\neventually cased to 2963 m. No further problems developed. From sea bed to 277\r\nm the initial dri","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"140","properties":{"OBJECTID":140,"wlbNpdidWellbore":143,"wlbName":"25/11-1","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 25/11-1 is located on the Utsira\r\nHigh in the Northern North Sea. The objective of the well was to test the\r\nhydrocarbon potential of the sedimentary section; to investigate the lithology\r\nand sequence in this portion of the North Sea basin; and to partially fulfil\r\nEsso's drilling obligation to the Norwegian Government incurred on behalf of\r\nthe Licenses.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 25/11-1 was spudded with the\r\nsemi-submersible installation Ocean Traveler on and drilled to TD at 2459 m in Basement\r\nrock. Actual drilling problems with the 25/11-1 were few. However, other major\r\nproblems occurred. The number 2 column of Ocean Traveler was bumped by a supply\r\nboat on 6 November and began taking water. On 18 November, 1966 the rig was towed to Stavanger for repairs. By 14 April, 1967 the rig was able to continue drilling at the 25/11-1 location. Bad weather caused a new break in the\r\ndrilling operations from 17 April to 10 May. \u003c/p\u003e\r\n\r\n\u003cp\u003eFrom the sea floor to 370 m (1213'), the\r\nhole was drilled with sea water and gel. Returns in this interval were to the\r\nsea floor. Below 370 m to total depth a sea water slurry with Bentonite,\r\nZeogel, Spersene, XP-20, Caustic Soda and 0 -12% diesel oil was used. \u003c/p\u003e\r\n\r\n\u003cp\u003eFirst show in the well was reported in\r\nthin siltstone and sandstone bands at ca1690 m. Gas and live oil were found in\r\nPaleocene clastic sediments (Balder Formation; top has been set at 1698). The\r\nrecovered cores from this interval (1726.7 to 1745.9 m) showed a predominantly\r\nshale section containing interbedded tuffaceous siltstone and sandstone. The\r\nshale bled gas throughout and developed a film of oil along fractured surfaces.\r\nThe siltstone, though tight, bled oil at the base of most beds. The sandstone,\r\nwhether 1/2 inch or three feet thick, was saturated with live oil which gave a\r\nyellow fluorescence and a streaming yellow-white or blue-white cut. Two FIT\r\ntests at 1755 and 1777 m yielded oil and gas, while a FIT at 1801.4 m recovere","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"141","properties":{"OBJECTID":141,"wlbNpdidWellbore":144,"wlbName":"16/2-1","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 16/2-1 is located on the very\r\nwestern part of the Utsira High in the central part of the Vestland Arch. The\r\nUtsira High is a large, flat, fault bounded basement feature. The objective of\r\nthis early well in the North Sea was: "To test the hydrocarbon potential\r\nof the sedimentary section; investigate the lithology and sequence in this\r\nportion of the North Sea basin; and to partially fulfil Esso's drilling\r\nobligation to the Norwegian Government incurred on behalf of the Licences."\r\n\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 16/2-1 was spudded with the\r\nsemi-submersible installation Ocean Traveler on 11 July 1967 and drilled to TD\r\nat 1906 m, 33 m into basement rock. There were no noteworthy drilling problems\r\nencountered while drilling. Initial drilling from the sea floor to 381 m was\r\nwith seawater and gel without casing. Returns were to the sea floor. Below 381\r\nm to total depth of 1906 m, a seawater slurry with gel, CMC, Spersene, XP-20,\r\nCaustic Soda, Barite, and 0-10% diesel oil was used.\u003c/p\u003e\r\n\r\n\u003cp\u003eOil shows were seen on cores in tight\r\nCretaceous carbonate rocks in the Tor Formation. The shows were strong and\r\ncontinuous from top Tor Formation down to 1776 m, and then became patchy. These\r\nrocks were too impermeable to justify further tests in this well. Weak shows\r\nwere seen also in a thin Oligocene sand from 1256 m to 1263 m and in Eocene\r\nmudstones from 1631 m to 1637 m, Balder Formation. Dead oil/tar was observed in\r\nfractures in the basement rock. \u003c/p\u003e\r\n\r\n\u003cp\u003eFive cores were cut from 1739.5 m to\r\n1821.8 m in the Tor Formation chalk and two more cores were cut from 1879.1 m\r\nto 1883.7 m in the basement. Four Formation Interval Tests (FIT) were performed\r\nat 1748.9 m, 1733.4 m, 1642.6 m, and at 1738.2 m. The tests, one in Early\r\nTertiary shales and three in Late Cretaceous carbonates, did not show any\r\nhydrocarbons.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 9\r\nAugust 1967 as a well with shows.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo dr","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"142","properties":{"OBJECTID":142,"wlbNpdidWellbore":145,"wlbName":"9/8-1","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThe 9/8-1 well is located in the central\r\nwestern part of the Norwegian-Danish Basin in the North Sea. The objective was\r\nto test the hydrocarbon potential of the sedimentary section present on the\r\ncrest of a closed seismic structure interpreted to be a salt pillow.\r\nProspective reservoir sands were anticipated towards the base of the Tertiary,\r\nin the Early Cretaceous and in the Early Triassic. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 9/8-1 was spudded with the\r\njack-up installation Endeavour on 23 May 1968 and drilled to TD at 2176 m in\r\nthe Late Permian Zechstein Group. It was the first well drilled in Norwegian\r\nwaters with a jack-up platform. After the 36" conductor was set at 137 m,\r\nthe hole was drilled with a 17 1/2" bit to 411 m. While reaming the hole\r\nto 26", cavings and fill of shell fragments and gravel caused problems\r\nfrom about 300 m, necessitating the 20" casing to be set high at 360 m.\r\nThe only additional drilling problem of note was a twist off while drilling at\r\n1546 m. The fish was recovered in a few hours without difficulty. From here,\r\noperations were successfully carried out to TD. Initial drilling from the sea\r\nfloor to 1350 feet was with seawater and gel without casing. Returns were to\r\nthe sea floor. Below 1350 to TD at 7138 feet, a Spersene, XP-20, Salinex mud\r\nwith up to 10 % diesel oil was used.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe interpreted salt pillow structure was\r\nfound to be a piercement which breached the Triassic with the result that the\u003c/p\u003e\r\n\r\n\u003cp\u003eTriassic Bunter sand section was not\r\npresent in this well. Top Permian Zechstein evaporites at 2109 m were\r\nimmediately overlain by the Middle Jurassic Dogger formation. The Dogger\r\ncontained some porous sandstones (Sandnes Formation) but these had only weak\r\nshows in the uppermost few feet and the logs indicated high water saturation.\r\nBoth the Lower Cretaceous and the entire Tertiary section consisted mainly of\r\nclays. No sands were developed at the base of either the Lower Cre","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"143","properties":{"OBJECTID":143,"wlbNpdidWellbore":146,"wlbName":"16/7-1","wlbHistory":"\r\n   \u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e                                                                  \r\n                                                                                          \r\n   \u003cp\u003eWildcat well 16/7-1 is located in the                                               \r\n   Ling Depression between the Utsira High and the Danish Norwegian Basin. The            \r\n   main objectives were to test the hydrocarbon potential of the sedimentary              \r\n   section and to investigate the lithology and sequence in this portion of the           \r\n   North Sea basin.\u003c/p\u003e                                                                   \r\n                                                                                          \r\n   \u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e                                                   \r\n                                                                                          \r\n   \u003cp\u003eWell 16/7-1 was spudded with the                                                    \r\n   semi-submersible installation Ocean Traveller on 11 August 1967 and drilled to         \r\n   TD at 2781 m in salt of the Late Permian Zechstein Group. Initial drilling from        \r\n   the sea floor to 381 m was with seawater and gel without casing. Returns were          \r\n   to the sea floor. Below 381 m to a depth of 2150 m, a Spersene XP-20                   \r\n   Lignosulphonate mud with 3% to 8% diesel oil was used. From 2150 m to TD, the          \r\n   mud system contained salt saturated Spersene XP-20 Lignosulphonate mud with 5%         \r\n   to 9% diesel oil.\u003c/p\u003e                                                                  \r\n                                                                                          \r\n   \u003cp\u003eAfter cementing the 30-inch casing at 131                                           \r\n   m, the well was drilled to 213 m. On pulling out of the hole, it was found that        \r\n   the guide structure had sunk 5 m into the seabed or 2.5 m below the mud line.          \r\n   The ocean floor str","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"144","properties":{"OBJECTID":144,"wlbNpdidWellbore":147,"wlbName":"16/1-1","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 16/1-1 is located roughly midway\r\nbetween the Gudrun Discovery and the Balder Field in the North Sea. This early wildcat\r\nwell had the general objective to: " -test the hydrocarbon potential and\r\ninvestigate the lithology in this portion of the North Sea basin".\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well is Type Well for the Utsira\r\nFormation.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 16/1-1 was spudded with the\r\nsemi-submersible installation Ocean Traveler on 26 September 1967 and drilled\r\nto TD at 3203 m in the Late Cretaceous Hod Formation. No significant problems\r\nwere reported from the operations. Initial drilling from the sea floor to 392 m\r\nwas with seawater and gel without casing. Returns were to the sea floor. Below\r\n392 m to total depth, a seawater slurry with Bentonite, Zeogel, Spersene,\r\nXP-20, Caustic Soda, and 0-12% diesel oil was used.\u003c/p\u003e\r\n\r\n\u003cp\u003ePorous sandstone was observed in the\r\nMiocene, Oligocene, and Eocene. There were also Paleocene sands in the well.\r\nTraces of possible residual oil stain were encountered in cuttings and cores\r\nfrom the Oligocene and Eocene. In addition, questionable shows (non-fluorescent\r\ndead oil) were reported on cores from the Paleocene. However, neither the hot\r\nwire gas indicator nor chromatograph suggested the presence of hydrocarbons. \u003c/p\u003e\r\n\r\n\u003cp\u003eA total of 18 cores were cut from the\r\ndifferent formations within the Hordaland, Rogaland, and Shetland Groups,\r\nrecovering a total of 171 m core. The depth for core 2 is probably incorrect,\r\npossibly be five meter shallow due to malfunction of the bumper subs. FIT wire\r\nline fluid samples were taken in potential hydrocarbon-yielding beds at 1878.5\r\nm, 2532.9 m, and at 2592.3 m. Only water and mud were recovered. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 10\r\nDecember 1967 as a dry well.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was performed.\u003c/p\u003e\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"145","properties":{"OBJECTID":145,"wlbNpdidWellbore":148,"wlbName":"16/6-1","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThe 16/6-1 ("ODIN 1") is\r\nlocated on the Utsira High in the North Sea. The well was positioned crestally\r\non the southern tip of a big, seismically defined, horst feature. This horst,\r\ntrending N-S and sharply limited by faults on west, east and south sides, has\r\ninduced a vast anticline in his Mesozoic and Tertiary overburden. The well was\r\nprogrammed to investigate the sedimentary section down to pre-Permian\r\nformations.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 16/6-1 was spudded with semi-submersible\r\ninstallation Ocean Viking on 7 November 1967 and drilled to TD at 2061 m in\r\nbasement rock. The well was drilled with seawater down to 360 m, and with a\r\nseawater / Q'Broxin / CMC type mud from 360 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eGas shows (C1) were observed with a GAL\r\n21 type chromatograph while drilling the Tertiary series, mainly in the upper\r\npart with a maximum of 12 % at 630 m, decreasing to 2-3 % below 790 m. In the\r\nCretaceous, no gas was seen and only a very small show (0.02 %å was recorded at\r\nthe top of Jurassic shale. In the Utsira Formation 28 m net sand was\r\nencountered. The sands had high porosities, but were water wet. From 2019 m\r\nto2050.5 m a very rich Draupne source rock shale with 6 % to 7 %\u00A0 TOC was\r\npenetrated. The sequence is immature in the well position. At 2050.5 m 4.5 m of\r\nlithic sand was found directly overlying basement. The sand is probably a\r\nbasement "wash" which reflects the transition from an erosive stage\r\nto a depositional one. The lower 4 m of this sand had very good porosities (>32%)\r\nbut were also water saturated. Permian and Triassic objectives were not present\r\nin the well. One core was cut in basement from 2057 to 2060.5 m (TD) with 100 %\r\nrecovery. Two series of log-operations were run at 1362 m and 2060.5 m. Trouble\r\noccurred with gumbo type clay bridging the hole during the first operations and\r\nthree cleaning trips were necessary. No fluid samples were attempted. The well\r\nwas permanently abandoned as a d","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"146","properties":{"OBJECTID":146,"wlbNpdidWellbore":149,"wlbName":"7/11-1","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 7/11-1 was drilled on eastern side\r\nof the Breiflabb Basin in the southern North Sea, ca 3km from the UK Border. The\r\nmain objective was to test the hydrocarbon potential of the Tertiary and the\r\nMesozoic sediments. Specific objectives were Paleocene sandstone, the Late\r\nCretaceous carbonate section, and the Jurassic. Sandstones in the Early\r\nCretaceous and Triassic were seen as possible secondary targets.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 7/11-1 was spudded with the\r\nsemi-submersible installation Ocean Viking on 26 February 1986 and drilled to\r\nTD at 3974 m in Late Permian Zechstein Salt. The only significant drilling problem\r\nencountered was sloughing of shale between ca 1675 m and 2315 m. Deviation was\r\nnegligible above 3500 m, from where it increased from 4.5 deg to 11.5 deg at\r\napproximately 3960 m. The true vertical depth therefore probably is 4-5 m short\r\nof measured depth at TD. A Drispac-Flosal-Desco mud system was used to a depth\r\nof 3290 m. At this depth the system was converted to a sodium chloride saturated\r\nDrispac-Flosal-Desco system. The salt saturated system was used to total depth.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well proved gas and condensate in three\r\ntests in a 5 m thick intra-Balder Formation sand (DST 5) and the Forties\r\nFormation from top at 2904 m down to 2989 m (DST 3 and 4). Below this depth DST\r\n1 and 2 produced only minor amounts of hydrocarbons due to tight formation. Top\r\nsalt came in under the Late Cretaceous Hidra Formation at 3740 m.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThree cores were taken in the Paleocene\r\nsandstone in the intervals 2922.7 - 2932.8 m, 2932.8 - 2949.9 m, and 2952.9 - 2966.9\r\nm. A fourth core at TD had no recovery. No wire line fluid samples were taken.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=E","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"147","properties":{"OBJECTID":147,"wlbNpdidWellbore":150,"wlbName":"9/4-1","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 9/4-1 is situated northeast in the\r\nÅsta Graben in the Danish-Norwegian Basin. The chosen well location allowed\r\nmultiple Tertiary to Mesozoic prospects to be tested. The primary objectives of\r\n9/4-1 were Middle Jurassic and Early Triassic (Bunter) sandstones, while basal\r\nTertiary and Early Cretaceous sandstones and Late Cretaceous limestones were\r\nsecondary objectives.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well is Type Well for the Egersund\r\nFormation.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 9/4-1 was spudded with the\r\njack-up installation Endeavour on 31 Marc 1968 and drilled to TD at 2963 m in\r\nLate Permian Zechstein salt. Three casing strings were set in the hole.\r\nSeawater was used as drilling fluid down to 1106 m, from where an XP-20\r\nlignosulphonate type mud was used. When the drilling commenced after the\r\n30" conductor pipe was set, several drilling problems arose. The\r\ncirculation was lost, and the hole fell in repeatedly, so the conductor pipe\r\nhad to be re-driven and cemented several times until the hole conditions allowed\r\nthe 20" casing to be set. At 2963 m the drill pipe stuck in salt, and\r\nafter five days of unsuccessful fishing operations, it was decided to abandon\r\nthe hole. The lower part of the hole could not be logged due to the unrecovered\r\nfish.\u003c/p\u003e\r\n\r\n\u003cp\u003eTwenty-five net meter of Jurassic\r\nsandstone was penetrated in a sand body (Sandnes Formation) at 2288 m. The\r\nsection was water wet, but fair shows were logged in the upper 5 m of the sand.\r\nThe remainder had very scattered poor shows. Porosity averaged 25 percent and examination\r\nof sidewall cores indicated a clean permeable sandstone reservoir. The second\r\nprimary objective, the Bunter Sandstone, was represented by an estimated 60 m\r\nof thin interbedded sands and sandstones scattered throughout a thick Triassic\r\nsection composed predominantly of silty red brown to pastel claystones. Due to\r\nlack of logs the interpretation of the Triassic section is somewhat tentative.\r\nLate Cretaceous Chalk ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"148","properties":{"OBJECTID":148,"wlbNpdidWellbore":151,"wlbName":"16/9-1","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 16/9-1 is located in the Ling\r\nDepression between the Utsira High and the Danish Norwegian Basin. A relatively\r\nthick Jurassic/Triassic section was anticipated and was expected to contain\r\nporous sandstones. The main objectives were to test the oil and gas potential\r\nand investigate the lithology of the sedimentary section on an anticlinal\r\nstructure between salt dome features. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 16/9-1 was spudded with the\r\nvessel Glomar Grand Isle on 8 May 1968 and drilled to TD at 3654 m in salt of\r\nthe Permian Zechstein Group. Drilling operations were normal to 3654 m (TD),\r\nwhile drilling at this depth on 24 June 1968, a sudden storm struck the Glomar\r\nGrand Isle causing the drill pipe to part and drop in the hole. The top of the\r\nfish was at 859 m. A jet cutter was run, the drill pipe was cut at 3321 m and\r\nrecovered on 28 June. Attempts to recover the remaining fish failed and on 7-8\r\nJuly final logs were run to the top of the fish at 3321 feet. Following final logs,\r\nthe well was prepared for abandonment. Initial drilling from the sea floor to\r\n402 m was with seawater and gel. Returns were to the sea floor. Below 402 m to\r\n3395 m, the mud system consisted of a sea water/Spersene/XP-20 Salinex mud with\r\n5% to 8% diesel oil. From 3395 to TD a salt saturated mud system was used.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe Danian and Cretaceous carbonates had\r\nno shows. The remaining sections penetrated by the well were predominantly\r\nclays, shales or evaporites. The well penetrated a 169 m Jurassic section and a\r\n735 m thick Triassic sequence before entering the Late Permian Zechstein Group\r\nat 3199 m. Some porous sandstones were present in the Jurassic and Triassic on\r\nstructure but these had no hydrocarbon shows and were indicated to be water\r\nbearing on the electric logs. Two conventional cores were cut, one from 1227 m\r\nto 1245 m in the Tertiary Hordaland Group and one from 2396 m to 2404.5 m in\r\nthe Middle Jurassic Vestland Group. No fluid samples were tak","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"149","properties":{"OBJECTID":149,"wlbNpdidWellbore":152,"wlbName":"9/4-3","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 9/4-3 was drilled on a salt-induced,\r\nanticlinal structure in the Egersund Basin in the North Sea, 17 km to the east\r\nof the 9/4-1 location. The primary objective was the Middle Jurassic sandstone,\r\nbut also Triassic sands were considered prospective. Danian and Late Cretaceous\r\nchalks were seen as secondary objectives.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well is Type Well for the Jurassic\r\nBryne, Sandnes, Tau, and Sauda Formations in the Norwegian-Danish Basin.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 9/4-3 was spudded with the\r\njack-up installation Ocean Tide on 14 July 1972 and drilled to TD at 2682 m in\r\nLate Triassic sediments of the Skagerrak Formation. The hole was drilled\r\nwithout significant drilling problems, although heaving shales in the lower\r\nTertiary caused some difficulties. After drilling out the 20" casing shoe\r\nat 404 m the drilling fluid was changed from a gelled seawater gel to a\r\nlignosulphonate seawater mud system, which was used to TD. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe only sandy Formation encountered\r\nabove the Jurassic level was the Late Paleocene Fiskebank Formation at 1150 m,\r\nwith a 50 m thickness. A complete sequence of Early Cretaceous stages was\r\npresent between 1967 and 2250 m. The Kimmeridge section also appeared complete\r\nand represented entirely by an argillaceous succession. No sandy facies of\r\nEarly Kimmeridgian/ Late Oxfordian was detected. The Bathonian-Bajocian\r\nsandstone/shale sequence between 2490 m to 2613 m (the Vestland Group) is\r\ncomparable with adjacent wells in the area although clearly thicker in the\r\ncurrent section. No oil shows were recorded in any section of the well during\r\ndrilling and the logs confirmed that the Jurassic and Triassic sections were\r\nwater wet. \u003c/p\u003e\r\n\r\n\u003cp\u003eFrom organic geochemical analyses source\r\nrocks were found in shales of the Late Jurassic Tau and Egersund Formations,\r\nand the coals of the Middle Jurassic. The 37 m thick Tau Formation at 2400 m\r\ncontained an average kerogen type II/III with TOC around 5% and has a r","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"150","properties":{"OBJECTID":150,"wlbNpdidWellbore":153,"wlbName":"17/4-1","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 17/4-1 was drilled on a NNE-SSW\r\ntrending monocline in the Ling Depression between the Sele High and the Utsira\r\nHigh /Patch Bank ridge. The objective was to investigate the sedimentary\r\nsection down to the pre-Permian, and particularly to test the hydrocarbon\r\npotential of the Mesozoic sands and Zechstein dolomites. Furthermore, Early\r\nPermian and/or pre-Permian reservoirs were to be evaluated if present.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 17/4-1 was spudded with the\r\nsemi-submersible installation Ocean Viking on 15 June 1968 and drilled to TD at\r\n3997 m in conglomerate in the Early Permian Rotliegend Group. Initial drilling\r\nto 444 m was with seawater, and the returns were to the sea floor. The 17\r\n1/2" hole was drilled out using an LFC-LC/sea water type mud, and the 13\r\n3/8" casing shoe was set at 1803 m. From this depth the mud system was\r\nsalt saturated. The 12 1/4" hole was drilled down to 3942 m from where the\r\nhole diameter was reduced to 8 1/2". An inverted oil-base mud was used from\r\n2900 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eSandstones were encountered in the\r\nJurassic and Triassic. They had medium to good porosities, but generally poor\r\npermeabilities due to calcite cement. The pre-Zechstein conglomerate was very\r\ntight with no porosity. On top of this there were nearly 1200 m of evaporites,\r\napparently undisturbed by halokinesis. The evaporites were overlain by around\r\n300 m of continental Triassic deposits. The Jurassic consisted of fluvial\r\nsandstones overlain by carbonaceous dark shales belonging to the Late Jurassic\r\n"hot" shale (Draupne Formation). This shale was penetrated at 2122 m\r\nand is 95 m thick in the well position. No samples of any kind was recovered\r\nfrom this interval, but analysis of caved cuttings believed to originate from\r\nDraupne indicated TOC in the range 2 % to 7 % with potential for oil and gas.\r\nThe Draupne formation is immature in the well. The Early Cretaceous marine, low\r\nenergy shales range in age ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"151","properties":{"OBJECTID":151,"wlbNpdidWellbore":154,"wlbName":"1/3-1","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 1/3-1 was drilled on the crest of a\r\nsalt-induced anticline on the Hidra High in the North Sea. The purpose of the\r\nwell was to investigate Tertiary and Mesozoic sequences down to top salt.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well is Type Well for the Våle, Hidra,\r\nHod, and Tor Formations, and Reference Well for the Vidar, Ekofisk and Blodøks Formations.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 1/3-1 was spudded with the four leg\r\njack-up installation Orion on 6 July 1968 and drilled to TD at 4877 m in the\r\nPermian Zechstein Group. From the deviation survey it is seen that the well\r\nstarts to deviate significantly at 4037 m (8 deg deviation), and at TD the\r\ndeviation is 18 deg. This will correspond to a TVD RKB that is ca 25 m less\r\nthan MD RKB.\u003c/span\u003e\u003cspan lang=EN-GB\u003eSeveral drilling\r\nproblems occurred during the drilling operations of well 1/3-1. While drilling\r\nthe 17 1/2" hole for the 20" casing, circulation losses started at\r\n220 m (720') and became total at 238 m (781'). While drilling on with sea\r\nwater, without returns, the pipe stuck. The lost circulation zone eventually\r\nhad to be sealed off with a cement plug. In the Tertiary plastic clays the\r\nproblems included tight hole conditions, bit balling, and difficulties in\r\nlowering the logging tools. The mud weight had to be raised from 10.8 ppg to 13.6\r\nppg to stabilize the hole. At 4131 m (13554') the bit twisted off, but was\r\nretrieved on the second fishing run. A hydrocarbon bearing zone was encountered\r\nat 4567 m (14984'). The mud became gas cut. At 4592 m (15064') the degasser was\r\noverloaded and the circulation lost, probably higher in the hole. A cement plug\r\nwas needed to combat the lost circulation problems. It was then decided to set\r\na 7" casing. Circulation was lost while running the casing, which had ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"152","properties":{"OBJECTID":152,"wlbNpdidWellbore":155,"wlbName":"2/8-2","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eExploration well 2/8-2 is located about 8\r\nkm south of the 2/5-3 Sørøst Tor Discovery. Danian and Maastrichtian limestones\r\nwere the main objectives. Another objective was to investigate if the Paleocene\r\nhydrocarbon bearing sandstones, which had been encountered in the Cod Field,\r\nextend across the 2/8-2 location. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 2/8-2 was spudded with the jack-up\r\ninstallation Orion on 28 June 1970 and drilled to TD at 3245 m in the Late\r\nCretaceous Rødby Formation. While drilling at approximately 1774 m large chunks\r\nof clay came over the shale shaker, followed by a gas kick at 1777 m. The mud\r\nweight was reduced to 10.0 ppg and degasser was run for two hours. Then the\r\nweight was increased to 14.1 ppg, the hole circulated and drilling continued.\r\nSloughing of shale occurred around 2490 m, and the mud weight was increased to\r\n14.3 ppg to control this problem. TD was reached and the well successfully\r\nlogged. Seawater was used for drilling the 36" hole down to 129 m. A seawater/\r\ngel mud was used to drill out the 36" casing and down to 427 m. From 427 m\r\nto TD the well was drilled with an Emulsite/Drill aid system with 2 to 5 %\r\ndiesel oil added. \u003c/p\u003e\r\n\r\n\u003cp\u003eOnly traces of sandstone and siltstone\r\nwere encountered in the Paleocene section, and the rocks showed no indications\r\nof hydrocarbons. Neither the Danian sequence, which was thinner than expected,\r\nnor the Maastrichtian limestones contained hydrocarbons. The only significant\r\nhydrocarbon shows encountered in 2/8-2 were from thin dolomite and limestone\r\nstringers of Eocene age. These exhibited good oil stains but generally showed\r\npoor porosities, and further evaluations were not made. Two cores were cut in\r\nthe well. Core l from 2962 m to 2971 m recovered 9 m of Danian chalk and core 2\r\nfrom 3231 m to 3238 m recovered 6.4 m of Rødby Formation shale. No fluid sample\r\nwas collected from the well. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 30\r\nJuly as a well with shows\u003c/p\u003e\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"153","properties":{"OBJECTID":153,"wlbNpdidWellbore":156,"wlbName":"7/11-2","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 7/11-2 was drilled , ca 1.5 km from\r\nthe UK Border on the eastern side of the Breiflabb Basin in the southern North\r\nSea. The objective was to test the hydrocarbon potential in the Paleocene on\r\nthe west flank of the Cod structure, and to confirm the gas and condensate\r\ndiscovery made by the 7/11-1 well. Well 7/11-1 tested up to 430 Sm3 condensate\r\nand 1254000 Sm3 gas /day from the Late Paleocene Forties Formation.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 7/11-2 was spudded with\r\nthe semi-submersible installation Ocean Traveller on 21 July 1968 and drilled\r\nto TD at 3427 m in the Late Cretaceous Tor Formation. Tight hole was\r\nexperienced when pulling out of the 17 12" hole. The hole was washed back\r\nto TD and mud weight increased to 14 ppg. Logging and casing operations could\r\nthen be successfully carried out. The well was drilled with sea water down to\r\n1219 m where the system was changed to a salt-saturated Drispac-Desco-Flosal\r\ntype.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well tested gas and condensate in\r\nPaleocene sandstones (the Forties Formation).\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eOne core was taken in the Paleocene\r\nsandstone in the interval 3030.6 m to 3045 m. No wire line fluid samples were\r\ntaken.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was permanently abandoned on as\r\na dry well.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eTesting\u003c/span\u003e\u003c/b\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThree drill stem tests were performed.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eDST 1 tested the interval 3166.3 m to\r\n3192.5 m. This test produced only 3.7 m3 salt water-cut mud and mud filtrate.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eDST2 tested the interval 3027.3 m to\r\n3105.9 m. ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"154","properties":{"OBJECTID":154,"wlbNpdidWellbore":157,"wlbName":"7/12-1 S","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 7/12-1 S was drilled on the Cod\r\nTerrace in the North Sea. The primary objective was to test possible Late\r\nPaleocene sandstones.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 7/12-1 S was spudded with\r\nthe jack-up installation Gulftide on 31 August 1968 and drilled to TD at 3311 m\r\nin claystone believed at the time to be Jurassic sediments but which since has\r\nbeen assigned to the Cromer Knoll Group. The pipe stuck at 2270 m. Fishing was\r\nunsuccessful and the well was plugged back and technically sidetracked from\r\n1443 m. The well was drilled with seawater/Flosal/Drispac down to 1009 m and\r\nwith seawater/Q-Broxin mud from 1009 m to TD. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was dry. The target section from\r\n2588 to 2627 m had only very thin laminations of sandstone without shows. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo cores were cut and no fluid samples\r\nwere taken.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was permanently abandoned on 18\r\nOctober 1968 as a dry well.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eTesting\u003c/span\u003e\u003c/b\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo drill stem test was performed. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"155","properties":{"OBJECTID":155,"wlbNpdidWellbore":158,"wlbName":"7/8-1","wlbHistory":"\u003cp\u003eWell 7/8-1 was drilled on an anticlinal\r\nstructure in the westernmost part of the Norwegian-Danish Basin and marginal to\r\nthe northern slope of the Central Through. The anticline was interpreted as a\r\nsalt-induced structure with closure at top Paleocene and top Cretaceous, and\r\nthese horizons were defined as the main objectives of the well. The well should\r\nbe drilled into Permian salt with prognosed top at 3261 m (10700 ft).\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 7/8-1 was spudded with the\r\nsemi-submersible installation Ocean Viking on 31 August 1968 and drilled to TD at 3334 m in Triassic sediments of the Gassum Formation. The well did not\r\nreach the planned TD in Permian salt.\u003c/p\u003e\r\n\r\n\u003cp\u003eDrilling went without significant\r\nproblems down to 1981 m. From this depth on, several drilling problems arose.\r\nAfter the casing had parted at two places the well had to be sidetracked from\r\n1831 m. This hole was then drilled to 3334 m, which is recorded as TD for the\r\nwell. At this depth the well kicked and the mud density was increased from 12.3\r\nppg to 12.8 ppg. While circulating, the hole gave up mud and sloughing finally\r\ncaused the pipe to stick. After having backed off the drill pipe and displaced\r\nthe hole with 14.0 ppg mud, a high pressure was observed on the drill pipe and\r\nthe mud system density was increased to 14.3 ppg. Several mud conditioning\r\noperations were necessary until the well seemed dead. After recovering 2650 m\r\nof drill pipe out of the hole the well was plugged from 2657 m to 2469 m and\r\ndisplaced with 14.7 ppg mud. A second sidetracked hole was then drilled from\r\n2538 m to 3316 m where the final logs were run. The operations were also\r\ndelayed significantly by severe weather conditions in December and January. The\r\nwell was drilled with seawater and high viscosity pills down to 1166 m, and with\r\na saturated salt water mud from 1166 m to TD. Below 1920 m the mud contained\r\nfrom 2 - 6 % oil.\u003c/p\u003e\r\n\r\n\u003cp\u003eBoth objective formations were encountered.\r\nHowever, both were thinner tha","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"156","properties":{"OBJECTID":156,"wlbNpdidWellbore":159,"wlbName":"7/11-3","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 7/11-3 was drilled ca 3.5 km\r\nsouth-east of the 7/11-1 Cod discovery well on the eastern side of the\r\nBreiflabb Basin in the southern North Sea. The objective was to test the extension\r\nof the Paleocene sands that were found hydrocarbon bearing in wells 7/11-1 and\r\n7/11-2.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 7/11-3 was spudded with\r\nthe semi-submersible installation Ocean Traveller on 17 October 1968 and\r\ndrilled to TD at 3350 m. The hole collapsed when drilling a shale section between\r\n1950 m and 2300 m. Bridging took place until the mud weight was increased to\r\n14.5 ppg. Otherwise the well was drilled without significant problems. The well\r\nwas drilled with a Drispac-Flosal-Desco system, which was salt saturated when\r\ndrilling the lower part of the hole.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eMinor amounts of oil and gas was tested\r\nin a Forties Formation sandstone sequence correlated to the best sandstone\r\nsequences that were tested in the two first Cod wells.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThree cores were cut in the intervals\r\n3074.2 to 3082 m, 3092.8 to 3105 m, and 3160.3 to 3177.2 m. No wire line fluid\r\nsamples were taken.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was permanently abandoned on 7\r\nJanuary 1969 as an oil appraisal well.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eTesting\u003c/span\u003e\u003c/b\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eEight drill stem testes were carried out.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eDST 1 tested the interval 3239.7 to\r\n3246.4 m. It produced a total of 15 m3 diesel cushion, mud and water. Bottom\r\nhole temperature was 129 deg C.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eDST 2 tested the interval 3210.2 to\r\n3231.8 m. It produced a total of ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"157","properties":{"OBJECTID":157,"wlbNpdidWellbore":160,"wlbName":"2/6-1","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 2/6-1 is located on the north\r\neastern slope of the Mandal High between the Søgne Basin and the Central Graben\r\nin the North Sea. It was drilled on a salt induced anticlinal structure. The\r\nobjective of the well was to investigate the sedimentary section down to the\r\nPermian salt, and particularly to test the hydrocarbon potential of the\r\nTertiary and Mesozoic sands. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 2/6-1was spudded with the semi-submersible\r\ninstallation Ocean Viking on 21 April 1969 and drilled to TD at 3336 m in salt\r\nbelonging to the Late Permian Zechstein Group. Down to 615 m the well was\r\ndrilled with sea water as drilling fluid, and the returns were to the sea\r\nfloor. From 615 m to TD a sea water/LFC type mud was used. The only significant\r\ndrilling problem occurred at a depth of 3220 m in the top of the Mesozoic sands\r\nwhen the well kicked 6.35 m3 of water associated with a gas show. The flow rate\r\nwas 20 m3/hr and the pressure was estimated to 480 kg/cm2. The kick was killed\r\nwith a 1.65 g/cm3 mud.\u003c/p\u003e\r\n\r\n\u003cp\u003eForty meter of Middle and Late Jurassic\r\nsands revealed good reservoir properties, but contained no hydrocarbons.\r\nAverage reservoir properties in these sands were 20% porosity and 140 mD permeability.\r\nThe Tertiary sediments contained very little sand. Shows were described as\r\nfollows: in the Paleocene siltstones and shales, a small chloroform cut was\r\nobtained on sidewall samples and in the Mesozoic sands, traces of bitumen occur\r\nand a chloroform cut was obtained. One conventional core of Jurassic sandstone\r\nwas cut at 3223 to 3235 m. No wire line fluid samples were taken.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 30\r\nMay 1969 as a dry well.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was performed.\u003c/p\u003e\r\n\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"158","properties":{"OBJECTID":158,"wlbNpdidWellbore":161,"wlbName":"17/10-1","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 17/10-1 is situated in the\r\nNorwegian- Danish Basin near the western margin of the Sele High, which is a\r\nshallow basement feature. The structure on which the well was drilled is a very\r\ngentle anticline in an area with prominent salt walls. The objective of the\r\n17/10-1 well was to test the Mesozoic section.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 17/10-1 was spudded with the\r\nsemi-submersible installation Sedneth I and drilled to TD at 3590 m in the\r\nTriassic Smith Bank Formation. The hole was drilled with a 18 1/2" bit to\r\n160 m, but during enlarging with a 36" hole opener the temporary guide\r\nbase sank 2.5 m into the seabed and tilted, due to heavy washing out. This made\r\nit impossible to enter the hole and the rig was moved 30 m NNE of its original\r\nposition where a new hole was spudded. An 18 1/2" hole was drilled to 430\r\nm. Seawater was used as drilling fluid and the returns were to the sea floor.\r\nThereafter the mud system was converted to a Spersene/XP-20 seawater mud. At\r\n3367 m the mud was converted to a salt saturated system since this was below\r\nthe prognosed depth for top Zechstein salt. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe chief reservoir zone of interest was\r\nthe massive Jurassic/Triassic sandstone (Gassum and Skagerrak Formations) from\r\n2682 m to 3405 m. This section had porosities mainly between 20 % and 25 % and\r\nwas entirely water bearing. There is a major unconformity on top of these sands\r\nto the overlying Late Jurassic shales. The claystone section from about 2651 m\r\nto 2682 m (Tau and Egersund Formations) had an exceptionally high gamma ray\r\nwith readings up to 300 API units. Resistivities varied between 2 and 7 ohm/m\r\ncompared with 1 - 1.5 ohm/m for the overlying shales. Cuttings from this\r\nsection were very carbonaceous and were bleeding gas when first examined. Chromatograph\r\nreadings were up to 700 ppm C1 with small quantities of C2, C3, and C4. Above\r\nand below this section the C1 reading was about 300 ppm. Nearly 700 m of Lower\r\nCretaceous s","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"159","properties":{"OBJECTID":159,"wlbNpdidWellbore":162,"wlbName":"2/3-1","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 2/3-1 is located approximately in\r\nthe centre of the block on the Sørvestlandet High. The aim of the well was to\r\ntest potential reservoirs in the Tertiary, Cretaceous, Jurassic, and Trias.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 2/3-1 was spudded with the\r\nsemi-submersible installation Ocean Traveler on 10 February 1969 and drilled to\r\nTD at 2934 m in the Late Permian Zechstein Group. Bad weather with wind up to\r\n31 m/s caused the rig to drift up to ca 40 feet off location on several\r\noccasions, interrupting drilling operations. The well was drilled with seawater\r\nand bentonite down to 463 m. A water based mud system was used in the remaining\r\nborehole.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well encountered gas in two zones in\r\nOligocene. From log analyses most of the reservoir interval from 1623 m to 1636\r\nm, except a shale break, had a porosity around 22% with Sw = 30%.á Best part of\r\nthe second zone had a porosity of 23% with an Sw of 23%, (1597 m to 1600 m). No\r\ncores were cut in the well and no fluid samples were taken other than during\r\nthe tests.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned as a\r\ngas discovery on 3 April 1969.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eSeven inch casing was run to 1673 m and\r\ntwo flowing drill stem tests were made successfully.á The first test was made\r\nfrom perforations at 1624 m to 1636 m and flowed dry gas at rates of 207000 to\r\n304000 Sm3/day on choke sizes varying from 24/64" to 30/64". The\r\nsecond test flowed dry gas at rates of 40000 to 92000/day on choke sizes\r\nvarying from 12/64" to 3O/64" from perforations at 1588 m to 1600 m.\u003c/p\u003e\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"160","properties":{"OBJECTID":160,"wlbNpdidWellbore":163,"wlbName":"9/12-1","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 9/12-1 is located in the North Sea,\r\nin the Danish-Norwegian Basin west of the Krabbe Fault Zone and Lista Fault\r\nBlocks. It was drilled near the crest of a salt induced anticlinal feature. The\r\nwell is very similar to the 9/8-1 well, but the various geological units are\r\nsomewhat thinner in 9/8-1. The objective of the well was to test the Tertiary\r\nand Mesozoic sequences.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 9/12-1 was spudded with the\r\nsemi-submersible installation Sedneth I on 28 March 1969 and drilled to TD at\r\n2698 m in the Triassic Smith Bank Formation. The 36" hole was drilled to\r\n133 m and the 30" casing was run to 131 m. An 18 1/2" hole was\r\ndrilled to 403 m, and two joints of 20" casing were hung from the 30"\r\nhousing before the 13 3/8" casing was set at 395 m. Seawater was used as\r\ndrilling fluid in the 36" and 18" holes and the returns were to the\r\nsea floor. After the setting of the 13 3/8" casing the mud system was\r\nconverted to a Spersene/ XP-20 seawater mud, which was used to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well encountered porous Danian/Late\r\nCretaceous limestones as well as Triassic and Jurassic sandstones, but no\r\nhydrocarbons. The Triassic was represented by about 600 m of continental red\r\nbeds. There was a major unconformity to the overlying 65 m thick Middle\r\nJurassic sandstones, which represent a marginal marine, deltaic environment.\r\nThe Late Jurassic consisted of 165 m of mainly dark shales. During the Early\r\nCretaceous in excess of 300 m of shales were deposited in the area while the\r\nLate Cretaceous is represented by 375 m of carbonates. From the Tertiary on the\r\nsedimentation turned to a clastic regime. Deposition of fine-grained sediments\r\nprevailed although this was interrupted by the deposition of more sandy units.\r\nThe Tertiary is made up of about 1200 m of sediments in this well. Late\r\nJurassic source rocks were confirmed by the well, but were found immature. The\r\nabsence of hydrocarbons ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"161","properties":{"OBJECTID":161,"wlbNpdidWellbore":164,"wlbName":"7/3-1","wlbHistory":"\r\n\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eExploration well 7/3-1 was drilled on the\r\nSørvestlandet High close to the Western part of the Danish Norwegian Basin.\r\nObjectives were to test all horizons down to Permian Rotliegendes. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe well is Reference well for the Ran\r\nSandstone Units. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 7/3-1 was spudded with the jack-up\r\ninstallation Orion on 7 April and drilled to TD at 4699 m in carbonates of an\r\nassumed pre-Permian age. Seawater was used to drill the 36" hole and\r\nreturns were to the sea floor. A sea water/ Spersene/XP-20 mud was used to a\r\ndepth of 2735 m, approximately to the top of the rock salt. The mud system was\r\nthen converted to an invert emulsion oil based mud, which was used to TD. While\r\ndrilling at 4699 m (TD) a salt water flow occurred and contaminated the mud.\r\nThe flow was controlled, but the condition of the hole was bad and the lower\r\napproximately 120 m of the well, therefore, has not been logged. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe well penetrated relatively complete\r\nTertiary, Cretaceous, Late Jurassic, and the Permian sequences. The Triassic\r\nand the Early Jurassic were missing. The Permian Zechstein salt was 1437 m\r\nthick, resting on a thin Kupferschiefer sequence. None of the sedimentary\r\nsequences penetrated contained significant amounts of hydrocarbons. Three conventional\r\ncores were cut in the interval from 4380.6 m to 4575.4 m from the Zechstein\r\nsalt and into the Rotliegendes Group. No fluid samples were taken. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned 10\r\nJune 1969 as a dry well.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was performed\u003c/p\u003e\r\n\r\n\r\n\r\n\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"162","properties":{"OBJECTID":162,"wlbNpdidWellbore":165,"wlbName":"1/3-2","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 1/3-2 was drilled on the crest of a\r\nsalt-induced anticline on the Hidra High in the North Sea.\u003c/span\u003e\u003cspan lang=EN-GB\u003eThe main objective was possible L. Tertiary\r\nsands, well developed and productive in Phillips 7/11-1. Secondary objective\r\nwas the Late Cretaceous chalky limestone, which had given shows in 1/3-1.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 1/3-2 was spudded with the\r\nsemi-submersible installation Sedneth I on 14 May 1969 and drilled to TD at\r\n4297 m in the Early Cretaceous Sola Formation. When drilling out of the\r\n20" casing shoe, circulation was lost immediately, and the lost\r\ncirculation zone had to be cemented off. The plastic clays caused continuous\r\ntroubles, such as bit balling and plugged shaker screens, and the hole had to\r\nbe reamed and washed several times. Below 3378 m diamond bits were used, and\r\nthe drilling was interrupted frequently because of leaking bumper subs. The\r\nwell was drilled water based with a 1 - 4 % addition of diesel through most of\r\nthe well bore.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eTertiary sands were not developed, and\r\nwhilst thick Late Cretaceous chalky limestone was found as predicted, there\r\nwere no hydrocarbon bearing intervals in it, and reservoir qualities were poor.\r\nNo source rock intervals were encountered, and only very minor traces of higher\r\nhydrocarbons were detected in the Late Paleocene-Early Eocene section, and in\r\nthe interval 3761 to 3901 m in the Hod Formation.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eA small core recovered by junk basket was\r\ntaken at 3589.02 - 3589.5 m. No wire line fluid samples were taken.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was permanently abandoned on 27\r\nJuly 1969 as a dry well.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eTesting\u003c/span\u003e\u003c/b\u003e\u003c","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"163","properties":{"OBJECTID":163,"wlbNpdidWellbore":166,"wlbName":"8/10-1","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eExploration well 8/10-1 was drilled on a\r\ngentle salt dome structure about 12 km west of the Ula Field on the\r\nSørvestlandet High. The objectives were to test Tertiary and Mesozoic horizons.\r\nMore specifically, the well should test the Tertiary Miocene section equivalent\r\nto the gas-bearing sand section in well 2/3-1 (35 miles southeast), Eocene\r\nsands which had minor gas shows in well 7/8-1 (25 miles northwest) and with oil\r\nshows in the Shell 1/3-1, Paleocene sands productive in the Cod Field (25 miles\r\neast), fractured Upper Cretaceous limestone with condensate and gas shows in\r\nwell 1/3-1 (20 miles southwest), and Jurassic and Triassic sands that were very\r\nporous and permeable in well 7/8-1. The latter also had small shows in wells 7/8-1\r\nand 9/4-1 (50 miles northwest).\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was spudded with the\r\nsemi-submersible installation Ocean Viking on 30 May 1969 and drilled to TD at\r\n3099 m in the Late Permian Zechstein Group. The hole deviation increased\r\nconsiderably from about 2225 m to TD, with a maximum of 13.5 degrees at 2774 m\r\nand about 10 degrees at the last survey point at 3018 m. Assuming an average\r\ndeviation of 9 degrees from 2200 m to TD this results in 3089 m TVD RKB at TD.\r\nThe pipe stuck at 3042 m. It was worked free after spotting diesel and Mudban.\r\nOtherwise no significant problems were encountered during drilling operations.\r\nThe well was drilled with seawater down to 655 m, with a sea water/gel mud\r\nsystem from 655 m to 2134 m, and with a lignosulphonate type mud from 2134 m to\r\nTD. Below 655 m the well was drilled with 1 % to 8 % of diesel oil in the mud,\r\nwith the higher concentrations towards TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eNone of the sedimentary sequences\r\npenetrated by the well contained hydrocarbons. A more or less continuous\r\nTriassic section consisted of mainly shale /claystone with traces of sand. The\r\nLate Jurassic was represented by the Sandnes Formation sandstone and the\r\nKimmeridge Clay (Flekkefjord Formation). An un","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"164","properties":{"OBJECTID":164,"wlbNpdidWellbore":167,"wlbName":"7/11-4","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 7/11-4 is located ca 8 km north-east\r\nof the Cod Field in the North Sea. The objective of the well was to test the Late\r\nPaleocene "Cod Formation" sands, gas bearing in the Cod 7/11-1 and -2\r\nwells; and the Early Paleocene, Danian, which had gas and oil shows in the\r\n7/11-1 well. Other objectives with possible but less likely development of\r\nporosity were sands of the Late - Middle Eocene and the top of the Late\r\nCretaceous chalk.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 7/11-4 was spudded with the\r\nsemi-submersible installation Ocean Viking on 2 July 1969 and drilled to TD at 3321 m in the Late Cretaceous Tor Formation. No significant problems were\r\nencountered in the operations.\u003c/p\u003e\r\n\r\n\u003cp\u003eNone of the objectives, the Late - Middle\r\nEocene, the Paleocene Forties Formation, the Danian,\r\nor the Late Cretaceous materialized as productive zones. Sand was lacking in\r\nthe Eocene, and was shaly and tight in the top of the Paleocene Rogaland Group.\r\nOnly 9 m net of porous sand was encountered in the interval 3082 - 3098 m in\r\nthe Middle and Lower Rogaland Group. This was below the postulated water table\r\nand from logs the net sand interval was water wet. Sands in the Danian section were\r\ntight and calcareous, and no porosity was present in the Late Cretaceous chalk.\r\nShows reported from SWC's from the well were described as "oil\r\nspecks" and "bituminous specks" in sandstones and shales in the\r\ninterval 3024 - 3093 m in the Rogaland Group.\u003c/p\u003e\r\n\r\n\u003cp\u003eNo cores were cut and no wire line fluid\r\nsamples were taken.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 31 July 1969 as a dry well.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe next well on the structure, well\r\n7/11-5, was drilled in 1982 and found oil in Jurassic Ula sands.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was performed.\u003c/p\u003e\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"165","properties":{"OBJECTID":165,"wlbNpdidWellbore":168,"wlbName":"2/11-1","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eExploration well 2/11-1 is located on the\r\nsouthern periphery of the Valhall Field in the North Sea. The objective of this\r\nearly wildcat was to test all horizons down to the Rotliegendes, estimated at\r\n14100 ft (4298 m). Top Permian was expected at 10300 ft (3139 m). Planned TD\r\nwas at 15000 ft (4572 m).\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well is Reference Well for the\r\nÅsgard, Sola, and Rødby Formations.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell was spudded with the\r\nsemi-submersible installation on and drilled to TD at 4691 m in the Late\r\nJurassic Tyne Group. The well started to build angle from below ca 3500 m with\r\nmaximum 11 deg deviation at 4444 m. Otherwise no significant drilling problems\r\nwere reported from this deep well. The well was drilled water based down to\r\n3432 m and with an invert oil mud (Vertoil) from 3432 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eTop Paleocene, Balder Formation, was\r\nencountered at 2590 m. Top chalks of the Shetland Group (Tor Formation) was\r\nencountered at 2635 m. In addition to shows from the gas detector, free oil was\r\nseen floating on the mud pits and samples showed good fluorescence and cut\r\nthrough the interval 2585 m to 2633 m (Balder, Sele, and Lista Formations).\r\nPost-well geochemical analyses reported significant oil staining down to 2776\r\nm. By testing live oil was confirmed in the uppermost Tor Formation. The tests\r\nwere inconclusive with regard to an OWC, but the logs indicated that the\r\ncontact was at 2655 m. Base Cretaceous was at 3555 m. The well did not reach\r\nPermian sediments; in stead the well drilled 1136 m in Late Jurassic shale\r\n(Mandal, Farsund and Haugesund Formations) before final TD was set. One\r\nconventional core was cut from 3864 to 3878 m in the Farsund formation.No wire\r\nline fluid samples were taken. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 3\r\nOctober 1969 as a minor discovery. After the 2/8-6 Valhall Discovery well was\r\ndrilled 6 years later well 2/11-1 was re-classified to oil appraisal well for\r\nthe Valhall Field.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTest","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"166","properties":{"OBJECTID":166,"wlbNpdidWellbore":169,"wlbName":"2/3-2","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 2/3-2 is located on the\r\nSørvestlandet High north of the Søgne Basin and south of the Åsta Graben. The\r\nwell was drilled to determine if Oligocene - Miocene reservoirs were developed\r\noff the flanks of the 2/3-1 structure and if the hydrocarbon accumulations\r\ntested in the 2/3-1 well extended beyond the spill point of the structure.\r\nTotal depth of the well was planned in Lower Oligocene.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well is Reference Well for the Vade\r\nFormation.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eAppraisal well 2/3-2 was spudded with the\r\nsemi-submersible installation Ocean Traveller on 26 July 1969 and drilled to TD\r\nat 2297 m in Paleocene sediments. The water depth at the location is 58 m. The surface hole\r\nwas drilled to 299 m, to simulataneously run the 30 inch and 20 inch casings. Problems with stuck pipe occurred. High pump pressure and\r\ndifficulty in washing past 265 m required pulling out of the hole again. It was\r\nfound that two drill collars and the bit had backed off. A dive was made to\r\ndetermine if the fish was on the ocean floor. It could not be found. The hole\r\nwas abandoned and repositioned 20 m due east of the original location, for\r\nre-spudding. After this no significant problems occurred during drilling.\r\nThe 36\" and 26\" holes, down to 211 m were drilled with sea water and returns\r\nwere to the sea floor. The rest of the well was drilled with a Q-Broxin/Caustic type mud.\r\nAs in well 2/3-1 bridging caused problema during the logging operations. This was especially\r\nevident in the 17 1/2 inch hole, which had to be reamed and circulated. Still it turned out\r\nto be impossible to obtain an open hole GR/BHC-Sonic survey.\u003c/p\u003e\r\n\r\n\u003cp\u003eAt 1795 m a sandy sequence, the Vade\r\nFormation, was encountered. It was described as two sandstone beds, greenish\r\ngray, very fine grained, poorly consolidated, porous and permeable. The\r\nsandstone beds were separated by about 15 m of dark brown shale with thin\r\nstreaks of dolomitic limestone. Below the Vade sand only thin sand beds coul","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"167","properties":{"OBJECTID":167,"wlbNpdidWellbore":170,"wlbName":"11/10-1","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 11/10-1 was drilled in the eastern\r\npart of the Danish Norwegian Basin close to the borderline between the\r\nNorwegian and the Danish sectors. The well is situated close to the Kreps fault\r\nzone on the western flank of the Horns Graben. The main objectives of the\r\n11/10-1 well were to test the hydrocarbon potential of the Tertiary and the\r\nMesozoic formations. Well 11/10-1 is the first well in quadrant 11 and one of\r\nthe few wells drilled in the southeastern part of the Norwegian continental\r\nshelf so long.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 11/10-1 was spudded with the\r\nsemi-submersible rig \"Ocean Viking\" on 2 August 1969 and completed 19 August\r\nthe same year. The well was drilled at 63 m water depth and bottomed at a total\r\ndepth of 2430 m in a Triassic sand section without having encountered\r\nhydrocarbons in any of the targets.\u003c/p\u003e\r\n\r\n\u003cp\u003eThree casing strings were set in the\r\nwell. Sea water was used for the initial drilling down to 253 m. From this\r\ndepth down to 1023 m a sea water gel mud was used and from 1023 down to TD a\r\nsea water Q-Broxin mud system was the drilling fluid. No significant drilling\r\nproblems occurred during the drilling of this well.\u003c/p\u003e\r\n\r\n\u003cp\u003eNo samples are available from the sea\r\nfloor down to 305 m. From 305 to 430 m the sampled sequence consists of medium\r\nto coarse grained, subangular to subrounded, glauconitic sand and sandstone\r\nwith scattered rock fragments. The sand is generally unconsolidated and mostly\r\nclear quartz and is relatively well sorted. Carbonaceous material, plant\r\nremains and shell fragments occur throughout. Dolomitic limestone are also\r\npresent, increasing towards the bottom of the unit where the dolomite forms the\r\ncement of the sand. The underlying shales are dated Late Oligocene, the age of\r\nthe sandy section is questionable as the upper 300m of the well has not been\r\nsampled.\u003c/p\u003e\r\n\r\n\u003cp\u003eNo sandstones are developed in the\r\nRogaland Group which is much reduced in this well. The Upper Cretaceous","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"168","properties":{"OBJECTID":168,"wlbNpdidWellbore":172,"wlbName":"2/4-2","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 2/4-2 (originally termed\r\n2/4-1AX by the License) was drilled by Phillips as a replacement for well\r\n2/4-1, which was junked at 1662 m in Miocene sediments due to an oil kick and\r\nsevere circulation problems. The objective was to test the hydrocarbon\r\npotential of the Tertiary and top Cretaceous.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 2/4-2 was spudded with the\r\nsemi-submersible installation Ocean Viking on 18 September 1969 and drilled to\r\nTD at 3305 m in the Late Cretaceous Tor Formation. No significant problems\r\noccurred in the operations. The well was drilled with seawater and hi-vis pills\r\ndown to 619 m, and with lignosulphonate mud from 619 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well discovered oil in Danian and\r\nLate Cretaceous chalk (Ekofisk and Tor Formations). The oil was found in two\r\nreservoirs separated by a hard, grey and tight lime mudstone in the base of the\r\nEkofisk Formation. The upper, Ekofisk Formation reservoir was encountered at\r\n3033 m and continued down to the tight lime mudstone at 3183 m. The lower, Tor\r\nFormation reservoir extended from 3203 m to 3257 m. Comparison between DST oil\r\nfrom the Ekofisk Formation in well 2/4-2 and the Miocene "kick-oil"\r\nencountered in well 2/4-1 showed that the 2/4-1 Miocene oil is a heavier oil with\r\na higher asphaltene content and lower paraffin content than the 2/4-2 oil. \u003c/p\u003e\r\n\r\n\u003cp\u003eEight conventional cores were cut with a\r\ntotal of 48.5 m recovered. Core 1 was cut in Early Miocene from 1664 to 1679.4\r\nm, while cores 2 - 8 were cut in the Ekofisk and Tor Formations in the interval\r\n3051 m to 3280 m. No wire line fluid samples were taken\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was suspended on 24 December\r\n1969 as the Ekofisk Discovery well, the first economic petroleum discovery on\r\nthe Norwegian Continental Shelf.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eOne successful drill stem tests (DST 4)\r\nwas conducted in open hole in the interval 3159 to 3195.5 m at the base of the\r\nEkofisk Formation. It flowed 5.9 MMCFD (16706","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"169","properties":{"OBJECTID":169,"wlbNpdidWellbore":173,"wlbName":"25/8-1","wlbHistory":"\r\n\r\n\r\n\r\n\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 25/8-1 was drilled on the Utsira\r\nHigh in the North Sea. The main purpose was to test an Eocene structural\r\nclosure, up dip from oil-bearing Eocene sands in Well 25/11-1.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 25/8-1 was spudded with the vessel\r\nGlomar Grand Isle on 28 April 1970. Drilling operations were normal down to\r\n2606 m, which became TD in the well, 289 m into the Early Permian Undefined\r\nGroup. While drilling at this depth the drilling pipe parted. After recovering\r\nthe upper portion of the drill pipe the top of the portion left in the hole was\r\nfound to be at 2559. Attempts to recover the fish failed and after logging and\r\ntaking sidewall cores in the uncased hole the well was prepared for testing. Initial\r\ndrilling from the sea floor to 378 m was with sea water and gell. Below 378 m\r\nto 1311 m, the mud system consisted of sea water, spersene XP-20 salinex. From 1311\r\nm to TD fresh water, spersene XP-20 mud was used.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well penetrated several Tertiary sands\r\nabove the Paleocene (Utsira and Skade Formations). These sands were water wet,\r\nbut some methane was recorded in the upper part of the Utsira Formation.\u003c/span\u003e\u003cspan lang=EN-GB\u003eTwo Paleoocene sands (Hermod Formation at 1754.4\r\n- 1758.1 m and 1759.0 - 1763.0 m) were found. The sands were separated by a\r\nthin 1 m shale section. Upon testing, the sands were found to be capable of\r\nproducing approximately 429 Sm3 of 21.7 deg API gravity, low sulphur (0.77 to 0.80%)\r\noil per day. All other sands or reservoirs penetrated by the well, including\r\nthe Heimdal Formation at 1777 to 1812 m, were water wet without shows.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eSeven cores were cut in the well. Core no\r\n1 was cut from 1676.4 to 1684.9 m in the Balder Formation, cores no 2 t","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"170","properties":{"OBJECTID":170,"wlbNpdidWellbore":174,"wlbName":"2/4-4","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 2/4-4 (named 2/4-3X by operator\r\nPhillips) was drilled to appraise the southern segment of the 2/4-2 Ekofisk\r\ndiscovery. The Ekofisk discovery is located in the Central Trough in the\r\nsouthern Norwegian North Sea and its structure is an anticline, uplifted by\r\nhalokinetic movements of Permian salt. The objective of well 2/4-4 was to test\r\nthe Tertiary and the top of the Late Cretaceous. Planned total depth was 11000\r\nft (3352 m).\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 2/4-4 was spudded with the\r\nsemi-submersible installation Ocean Viking on 2 June 1970 and drilled to TD at\r\n3424 m in the Late Cretaceous Tor Formation. The well was drilled with seawater\r\nand hi-vis mud down to 622 m, and with seawater/drill-aid mud from 622 m to TD.\r\nTwo - six percent oil was added to the mud below 622 m.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe Shetland Group was encountered with\r\ntop Ekofisk Formation at 3116 m and top Tor Formation at 3259 m. Oil was tested\r\nin the Ekofisk Formation in various zones in the interval 3127 - 3225 m. The\r\nTor Formation produced only water.\u003c/p\u003e\r\n\r\n\u003cp\u003eTwo short cores were cut in the Ekofisk\r\nFormation and one 8-m core was cut in the Tor Formation. No fluid samples were\r\ntaken on wire line.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 1\r\nAugust 1970 as an oil appraisal.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eEight drill stem tests through\r\nperforations in the 7" liner were carried out, one in the Tor Formation,\r\nthe rest in the Ekofisk Formation. The Tor test produced only water, the\r\nlowermost test in Ekofisk did not produce liquid to the surface, but 100 ft\r\n(30.5 m) gas cut mud was reversed out of the test string. The next lowermost\r\nEkofisk test, DST 3 from 3233 - 3236 m, also produced water and no\r\nhydrocarbons. The remaining tests, all in the Ekofisk Formation gave oil.\r\nMaximum flow was obtained from the interval 3162 - 3200 m in DST 8 with 601 Sm3\r\noil /day on two 3/4" chokes. The oil gravity was in the range 34.2 - 35.6\r\ndeg API and the GOR was in the range 165 ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"171","properties":{"OBJECTID":171,"wlbNpdidWellbore":175,"wlbName":"10/8-1","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThe 10/8-1 well is situated close to the\r\nLista Nose in the eastern part of the Norwegian-Danish Basin. It was drilled on\r\na salt induced anticlinal structure related to a salt pillow. The structure is\r\nwell defined from the Permian salt up to the upper cretaceous chalk. It has a\r\nvertical closure of 300 m for a closed area of 80 km2 at a seismic horizon\r\nassumed to be the Jurassic sandstone. A fault cuts the unconformably underlying\r\nhorizons attributed to Triassic. The specific objective of the 10/8-1 well was\r\nto test the hydrocarbon potential of the Jurassic sandstone section, estimated\r\nto be 60 m thick, with additional reservoir being furnished by the Triassic\r\nsandstones immediately below. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe well is Type Well for the Skagerrak\r\nFormation and Reference Well for the Smith Bank Formation\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 10/8-1 was spudded with the\r\nsemi-submersible installation Pentagone 81 and drilled to TD at 2861 m in the\r\nLate Permian Zechstein salt deposits. The well was completed in 37 days without\r\nreported problems. The well was drilled with seawater with returns on the sea\r\nfloor down to 510 m, and with a LFC/sea water mud system from 510 m to TD. \u003c/p\u003e\r\n\r\n\u003cp\u003eOne thousand three hundred meter of\r\ncontinental deposits of Triassic age is present. On top of this is the Gassum\r\nFormation. The Early to Middle Jurassic was not encountered in the well. One\r\nhundred and fifty meter Late Jurassic sand and shale is directly overlying the\r\nGassum Formation. Around 200 m of shale was deposited during the Early\r\nCretaceous while the Late Cretaceous is represented by 425 m of lime mudstones.\r\nThe lower 200 m of the Tertiary was developed in mostly sandy facies. All\r\nFormations penetrated by the well were found water wet. The only show recorded\r\nwas traces of gas (C1 and C2) from 1010 m to 1050 m. Organic geochemical\r\nscreening analyses show TOC in range 0.1 - 1.5 % with the highest values in the\r\nLate Jurassic and Cretaceous sequences. The Tr","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"172","properties":{"OBJECTID":172,"wlbNpdidWellbore":176,"wlbName":"9/4-2","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 9/4-2 was drilled on a salt-induced,\r\nanticlinal structure in the Egersund Basin in the North Sea, 11 km to the north\r\nof the 9/4-1 location. The primary objective was the Middle Jurassic sandstone,\r\nbut also Triassic sands were considered prospective. Danian and Late Cretaceous\r\nchalks were seen as secondary objectives.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well is Type Well for the Base\r\nCretaceous Flekkefjord Formation in the Norwegian-Danish Basin.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 9/4-2 was spudded with the\r\njack-up installation Gulf Tide on 19 July 1970 and drilled to TD at 3025 m in\r\nthe Middle Triassic Skagerrak Formation. Three casing strings were set in the\r\nhole. The 20" casing was originally planned around 600 m but stopped short\r\nat 282 m where it had to be set. Except for this, the hole was drilled without\r\nsignificant technical problems. The hole was drilled with seawater as drilling\r\nfluid down to 99 m from where a seawater gel with spersene was used. Diesel oil\r\nwas used as emulsifier.\u003c/p\u003e\r\n\r\n\u003cp\u003eDanian and Late Cretaceous chalks were\r\npenetrated from 1323 m to 1936 m and were found water wet. The target Middle\r\nJurassic sands (Sandnes Formation) was encountered at 2490 m. The sand was\r\nwhite, medium to coarse grained, poorly consolidated, calcareous, with thin\r\ninterbeds of red to grey, micaceous shale. This sandstone appears to be an\r\nexcellent reservoir, of the total thickness of 50 m about 48 m appeared to be a\r\nporous sandstone on the logs with porosity of about 24 percent. The Triassic\r\n(Skagerrak Formation) was encountered at 2633 m. It consisted of red, soft,\r\noccasionally calcareous and micaceous claystone with interbedded red to white,\r\nfine to coarse grained, in part calcareous sandstone. No hydrocarbon shows were\r\nencountered in the well. No conventional cores were cut and no fluid samples\r\ntaken.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 29\r\nAugust as a dry hole.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was performed.\u003c/p\u003e","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"173","properties":{"OBJECTID":173,"wlbNpdidWellbore":177,"wlbName":"2/4-5","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 2/4-5 (named 2/4-4X by operator\r\nPhillips) was drilled to appraise the northern segment of the 2/4-2 Ekofisk\r\ndiscovery. The Ekofisk discovery is located in the Central Trough in the\r\nsouthern Norwegian North Sea and its structure is an anticline, uplifted by\r\nhalokinetic movements of Permian salt. The objective of well 2/4-4 was to test\r\nthe Tertiary and the top of the Late Cretaceous. Planned total depth was 11000\r\nft (3352 m).\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well is Type Well for the Ekofisk\r\nFormation.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 2/4-5 was spudded with the\r\nsemi-submersible installation Neptune 7 on 21 June 1970 and drilled to TD at\r\n3320 m in the Late Cretaceous Tor Formation. The well was drilled with seawater\r\nand hi-vis mud down to 585 m, with seawater/lignosulphonate mud from 585 to\r\n3217 m, and with seawater/drill-aid mud from 3217 m to TD. Below 584 m 2 - 5 %\r\ndiesel was added to the mud.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe Danian Chalk (Ekofisk Formation) was\r\nencountered at 3037 m and the Maastrichtian chalk (Tor Formation) was encountered\r\nat 3164 m. Both formations were hydrocarbon bearing. A total of 86.2 m core was\r\nrecovered in 12 cores in the interval 3094 to 3206 m in the Ekofisk and Tor\r\nFormations. No fluid samples were taken on wire line.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 27\r\nAugust 1970 as an oil appraisal.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eFive zones in the Ekofisk and Tor\r\nFormations were perforated for testing. \u003c/p\u003e\r\n\r\n\u003cp\u003eDST 1 and DST 1A tested the intervals\r\n3164 -3203 m and 3177 - 3186 m in the Tor Formation, respectively. DST 1\r\nproduced at maximum 165795 Sm3 gas and 701 Sm3 oil /day on a 24/64" choke.\r\nThe GOR was 236 Sm3/Sm3; the oil gravity was 37.3 deg API. The reservoir\r\ntemperature in the DST1 zone was reported to be 129.4 deg C. DST 1A was\r\nconducted with smaller choke sizes and gave somewhat lower rates than in DST 1,\r\nbut fluid properties were similar.\u003c/p\u003e\r\n\r\n\u003cp\u003eDST 2 tested the interval 3106 -3143 m in\r\nthe Ekofisk Formation, but was","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"174","properties":{"OBJECTID":174,"wlbNpdidWellbore":178,"wlbName":"2/5-1","wlbHistory":" \u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n \r\n \u003cp\u003eWildcat well 2/5-1 is located ca 10 km\r\n northeast of the Ekofisk Field. It was drilled on an essentially northwest -\r\n southeast striking anticlinal seismic structure extending into the adjacent\r\n block 2/4. \u003c/p\u003e\r\n \r\n \u003cp\u003eThe well is Reference Well for the\r\n Ekofisk Formation.\u003c/p\u003e\r\n \r\n \u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n \r\n \u003cp\u003eWell 2/5-1 was spudded with the jack-up\r\n installation Orion on 1 August 1970 and drilled to TD at 3972 m in Late\r\n Jurassic shales. At 2997 m cones of the bit was lost in the hole and five days\r\n were spent fishing for them. The well was planned vertical, and was essentially\r\n vertical with maximum deviation 1.5 deg down to 3238 m. From there deviation\r\n increased to 7.1 deg at 3639 m, 12.5 deg at 3821 m, 19.2 deg at 3932 m, and\r\n 21.9 deg at 3967 m. The well was drilled with seawater and bentonite down to\r\n 381 m and with a Drill aid/XP-20 mud with 3- 6 % diesel from 381 m to TD. \u003c/p\u003e\r\n \r\n \u003cp\u003eThe Danian limestone (Ekofisk Formation)\r\n was encountered at 3041. Then a Late Cretaceous succession was penetrated with\r\n chalks of the Tor and Hod Formations at 3132 m and 3475 m, respectively,\r\n followed by the Blodøks Formation shales at 3551 m and the Hidra Formation\r\n chalk at 3594 m. Commercial quantities of hydrocarbons were encountered and\r\n tested in the Ekofisk and Tor Formations. The well also penetrated 133 m of\r\n Late Jurassic source rock quality shales. Organic geochemical analyses of these\r\n shales showed TOC in the range 2 - 4 % and thermal maturity corresponding to\r\n late oil window (%Ro around 0.8), in well position. \u003c/p\u003e\r\n \r\n \u003cp\u003eTwenty-three conventional cores were cut\r\n in the chalk. Ten were cut in the Ekofisk Formation (75.2 m recovered), and\r\n thirteen in the Tor Formation (171.6 m recovered). No wire line fluid samples\r\n were taken.\u003c/p\u003e\r\n \r\n \u003cp\u003eThe well was permanently abandoned on 22\r\n November 1970 as an oil discovery.\u003c/p\u003e\r\n \r\n \u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n \r\n \u003cp\u003eOne open-hole DST and eight DSTs through\r\n liner perforation were performed. The op","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"175","properties":{"OBJECTID":175,"wlbNpdidWellbore":179,"wlbName":"2/7-1","wlbHistory":"\u003chtml\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003csp \u003c/span\u003e\u003c/p\u003ean lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 2/7-1 was drilled on the Eldfisk\r\nstructure on the Lindesnes Ridge in the North Sea. The primary objective was to\r\ntest the Late Cretaceous to Paleocene chalk sequence that had proved oil in the\r\nEkofisk structure north of Eldfisk. A secondary objective was to test older\r\nMesozoic sediments\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 2/7-1 was spudded with the semi-submersible\r\ninstallation Ocean Viking on 3 August 1970 and drilled to TD at 4573 m in the Vestland\r\nGroup. The well was drilled with seawater and hi-vis sweeps down to 588 m, with\r\nseawater/Drill Aid mud from 588 m to 3102 m, and with seawater/lignosulphonate\r\nmud from3102 m to TD. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eTop of the Danian chalk sequence, Ekofisk\r\nFormation, is at 2934 m, while top of the Cretaceous chalk, Tor Formation, is\r\nat 3014 m. In this first well on the structure, only small amounts of live hydrocarbons\r\nwere found in the Ekofisk carbonates.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThree cores were cut from 2956.6 to\r\n2987.3 m in the Ekofisk Formation. A fourth core was cut from 3032.8 to 3041.9\r\nm. No fluid sample was taken.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was permanently abandoned on 11\r\nDecember 1970 as an oil discovery\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eTesting\u003c/span\u003e\u003c/b\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eA drill stem test was performed in the\r\ninterval 2942 to 2954 m plus 2957 to 2975 m in the Danian chalk (Ekofisk\r\nFormation). The flow rate after acidizing was too small to measure. The\r\nrecovered fluid was composed of 65% oil and 35% water. The oil density was 32.2\r\n°API.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"176","properties":{"OBJECTID":176,"wlbNpdidWellbore":180,"wlbName":"25/10-2","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 25/10-2 was\r\ndrilled to test a structural closure on the down faulted west flank of the\r\nbasement high on which Esso wells 25/11-1 (Balder Discovery well), 25/8-1 and\r\n25/10-1 had been drilled. The original\r\nprimary objective, as stated in the Operator's Final Well Report from 1972, was\r\nEarly Paleocene to Late Eocene sands, which had a thin oil leg in the three\r\nwells drilled previously. It was\r\nanticipated that appreciably thicker Early Eocene sands would be encountered in\r\nthe oil leg of 25/10-2. Additional prospects were in Middle - Late Eocene\r\nsands, Danian carbonates, and sands of Early Cretaceous, Jurassic or Triassic\r\nage. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe results of the\r\nwell given below is reported with today's knowledge of the area (anno 2003) and\r\ncannot be compared directly with the original objectives.\u003c/p\u003e\r\n\r\n\u003cp\u003e \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 25/10-2\r\nwas spudded with the drilling vessel "Glomar Grand Isle" on 5 August\r\n1970 and drilled to TD at 2191 m (7187 feet) in the Paleocene Lista Formation.\r\nDrilling operations went without mechanical problems and there was no lost time\r\nwaiting on weather. Well 25/10-2 was suspended 25 August 1970 as a well with\r\noil shows. The well was re-entered (25/10-2 R) using "Glomar Grand\r\nIsle" on 2 May 1972 and drilled to a total depth of 3180.6 m (10435 feet)\r\nin basement rock. \u003c/p\u003e\r\n\u003cp\u003eAfter drilling out\r\nthe plug in the bottom of the casing in the re-entry some difficulty was\r\nexperienced in staying in the old hole.\r\nThe well was drilled to a depth of 2369 m where lost circulation was\r\nencountered. Later the pipe became stuck, with the bottom of the fish at 2213\r\nm, and it became necessary to sidetrack the hole. Six cones were lost in the hole while drilling at 2497 m in the\r\nsidetrack hole; otherwise no problems were experienced. Initial drilling from\r\nthe sea floor to 396 m was with seawater and gel. From 396 m to 1036 m the hole\r\nwas drilled with seawater / Spersene / XP 20 / Salinex sys","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"177","properties":{"OBJECTID":177,"wlbNpdidWellbore":181,"wlbName":"2/4-6","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 2/4-6 (named 2/4-5X by operator\r\nPhillips) was drilled on a structure ca six km west off the Ekofisk discovery.\r\nThe objective of the well was to test the Danian and Late Cretaceous limestone,\r\nwhich had proved oil productive in the other wells drilled within the block\r\n2/4. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 2/4-6 was spudded with the\r\nsemi-submersible installation Neptune 7 on 28 August 1970 and drilled to TD at\r\n3411 m in the Late Cretaceous Tor Formation. The well was drilled with sweater\r\nand hi-vis mud down to 585 m, with seawater/drill aid mud from 585 m to 3107 m,\r\nand with seawater lignosulphonate mud from 3107 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well penetrated a thick, nearly\r\ncomplete Tertiary succession consisting mostly of shales and claystones. A ca\r\n50 m thick sandy sequence with gas shows was encountered at 2956 m in the\r\nuppermost Paleocene. Danian Limestone (Ekofisk Formation) was penetrated at\r\n3110 m and Late Cretaceous limestone (Tor Formation) was encountered at 3270 m.\r\nA rich condensate and gas was tested from these formations\u003c/p\u003e\r\n\r\n\u003cp\u003eFive conventional cores were cut between\r\n3120.5 and 3223.4 m in the Ekofisk Formation. No wire line fluid samples were\r\ntaken.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 10\r\nDecember 1970 as a gas and condensate discovery\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eFive drill stem tests through\r\nperforations of the 7" liner were carried out. The following results are\r\nmaximum flow after acidization: \u003c/p\u003e\r\n\r\n\u003cp\u003eDST 1 tested the zone 3370 - 3374 m in\r\nthe Tor Formation. It produced only water at a rate of 13 m3 /day. Bottom hole\r\ntemperature (BHT) in the test was reported to be 136.7 deg C.\u003c/p\u003e\r\n\r\n\u003cp\u003eDST 2 tested the intervals 3271 - 3286 m\r\nand 3295 - 3310 m in the Tor Formation. This test flowed 568 Sm3 oil /day on a\r\n1" choke. Oil gravity was 42.8 deg API and the GOR was 452 Sm3/Sm3. The\r\nBHT was reported to be 133.9 deg C.\u003c/p\u003e\r\n\r\n\u003cp\u003eDST 3 tested the interval 3243 - 3246 m\r\nin the lower Ekofisk Forma","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"178","properties":{"OBJECTID":178,"wlbNpdidWellbore":182,"wlbName":"25/10-3","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 25/10-3 is located in the western part\r\nof the Balder Field complex on the Utsira High in the North Sea. Lower Eocene\r\noil sands had been encountered in Esso wells 25/10-1, 25/11-1 and 25/8-1. The\r\nobjective of 25/10-3 was to test the Eocene sand in a lower structural position\r\nto accurately establish the oil/water contact in the area; to determine their\r\nlateral continuity and if they would thicken towards the northwest.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 25/10-3 was spudded with the vessel\r\nGlomar Grand Isle on 27 August 1970 and drilled to TD at 1921 m in the Early\r\nPaleocene Ekofisk Formation. Except for stuck pipe at 1247 m, which was worked\r\nfree with Diesel oil and pipe lax in 4 hours, drilling operations were routine\r\nand trouble-free. The well was drilled with seawater/gel down to 402 m, with\r\nseawater Spersene/XP-20/Salinex mud from 402 m to 951 m, and with fresh\r\nwater/Spersene/XP-20 mud from 951 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe Oligocene to Recent sediments\r\nconsisted of clays and sands with no indications of hydrocarbons. The 518 m thick\r\nEocene section was chiefly grey to grey green clay shales with 6.7 m of wet sand\r\nin the interval 1401 m to 1413 m (Grid Formation), a 4 m oil-bearing sand from 1750\r\nto 1754 m (Intra Balder Formation sandstone), and a 1 m wet sand at 1799 m. The\r\n4 m oil sand had 32-36% porosity and tested 26 deg API gravity oil on a wire\r\nline formation test. Oil shows were observed in cuttings from 1716 m and down\r\nto the top of the oil bearing sand, and shows continued down to 1768 m, all through\r\nthe cored section. In addition to the Intra Balder Formation sandstone the\r\nPaleocene section penetrated was composed primarily of 3 sands interbedded with\r\ngrey green shale. From top to bottom the Paleocene sands were respectively 29 m\r\nth","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"179","properties":{"OBJECTID":179,"wlbNpdidWellbore":183,"wlbName":"9/10-1","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 9/10-1 is located in the Åsta Graben\r\nof the Danish Norwegian Basin in the North Sea. The location was selected to\r\nexplore the northeast regional limit of Oligocene sands at a non-structural\r\nsite and to reach the Danian very low on the South flank of the seismic\r\n"L" structure. The main objectives were the first and second\r\nOligocene sands, which were gas bearing in the 2/3-1 well. The location, in\r\naddition, tested for presence of the Danian section, which had proved to be oil\r\nbearing in the Phillips Ekofisk area approximately 40 miles to the Southwest.\r\nThere was also a possibility of the development of gas bearing zones within the\r\nMiocene section.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 9/10-1 was spudded with the\r\njack-up installation Gulftide on 30 August 1970 and drilled to TD at 2205 m in\r\nthe Late Cretaceous Tor Formation. A 38" hole was drilled to 143 m with\r\nseawater. After spotting a gel slurry, 36" drive pipe was set at 123 m.\r\nDrilling was continued with a 26" bit to 221 m using seawater where lost\r\ncirculation became excessive. Attempts with a 50-barrel LCM slurry and a\r\n300-sack cement plug were unsuccessful in sealing off the thief zone. The\r\ndrilling was continued "blind" to 251 m where a 450-sack gel slurry\r\nwas spotted and 20" casing run to 248 m and cemented. After installing\r\n20" BOP, 17 1/2" hole was drilled to 953 m using a 10.7 lb gel mud.\r\nThree attempts were made to log this surface section but hole bridging\r\nconditions occurring at 279 m and 457 m would not permit deeper penetration.\r\nWent into the hole with the bit, tagged bottom, and then drilled 5 m with no\r\nobstruction. The hole was conditioned and logged from 457 m to 88 m. Rigged up\r\nBHA and went to bottom with the bit, cleaned out to 957 m, and drilled an\r\nadditional 6 m. The 13 3/8'' casing was then run and set with no problems to a\r\ndepth of 960 m. Drilling continued with a 12 1/4" bit from under the 13\r\n3/8'' ca","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"180","properties":{"OBJECTID":180,"wlbNpdidWellbore":184,"wlbName":"25/11-2","wlbHistory":"\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 25/11-2 was drilled to appraise the\r\n25/11-1 Balder discovery on the Utsira High in the North Sea. The objective was\r\nto define the continuity and reservoir thickness of the Early Eocene oil\r\nbearing sands in a northward direction from well 25/11-1 and a southward\r\ndirection from well 25/8-1.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 25/11-2 was spudded with\r\nthe vessel Glomar Grand Isle on 13 September 1970 and drilled to TD at 1823 m\r\nin the Paleocene Sele Formation. No significant problems occurred during the\r\noperations. The well was drilled with seawater/gel down to 175 m, with seawater/Spersene/\r\nXP-20/Salinex from 175 m to 945 m, and with fresh water/ Spersene/XP-20 from\r\n945 to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well penetrated the Utsira Formation\r\nand several Skade Formation sand units and then entered a ca 600 m thick section\r\nof shales belonging to the lower Hordaland Group before top Balder formation was\r\nencountered at 1699 m. The Balder Formation contained several thin Intra Balder\r\nFormation sandstones, of which a seven meter thick sandstone at 1727 m was the\r\nthickest. The sands were oil bearing down to 1747 m. Hermod sandstones were\r\npenetrated from 1780 to 1817 m. They had better reservoir properties than the\r\nIntra Balder Formation sands, but were water bearing without shows.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo conventional cores were cut in the\r\nwell. Out of four attempts with the Formation Interval Tester (FIT) three tests\r\nwere seal failures while test no 4, at 1728.5 m, was successful and recovered\r\n0.33 Sm3 gas, 6.9 l oil, and 3.25 l oil and gas cut mud.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was permanently abandoned on 24\r\nSeptember as an oil appraisal.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"181","properties":{"OBJECTID":181,"wlbNpdidWellbore":185,"wlbName":"25/11-3","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 25/11-3 was drilled ca 1.5 km south\r\nof the 25/11-1 Balder discovery well on the Utsira High in the North Sea. The\r\nobjective was to test the reservoir continuity, sand correlation and possible\r\nthickening of the 25/11-1 Early Eocene oil sands in a South-easterly direction.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 25/11-3 was spudded with\r\nthe vessel Glomar Grand Isle on 25 September 1970 and drilled to TD at 1858 m\r\nin the Early Paleocene Ekofisk Formation. North Sea fall storms were the cause\r\nof drilling problems experienced on this well. Cumulative lost time due to\r\nwaiting-on-weather alone amounted to 23.3% of the total rig days. While at the\r\ndepth of 1228 m, one of the severe storms necessitated pulling the bit into the\r\n9-5/8 inch casing and hanging off the drill pipe. After the storm abated and\r\nthe hang off tool recovered, it was found that the 5 inch drill pipe extension\r\nbelow the tool had parted, allowing the drill string to fall to bottom.\r\nFortunately the fish was recovered in one run with an overshot. The hole was\r\nthen drilled to TD with no further problems. Initial drilling from the seafloor\r\nto 396 m was with sea water and gel. Below 396 to a depth of 960 m, the mud\r\nsystem consisted of seawater, Spersene XP-20 Salinex. From 960 m to TD fresh\r\nwater Spersene XP-20 mud was used.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well penetrated the Utsira Formation\r\nand several Skade Formation sand units and then entered a ca 600 m thick\r\nsection of shales belonging to the lower Hordaland Group before top Balder\r\nformation was encountered at 1711 m. Only thin Paleocene sands were\r\nencountered, and all were water wet without shows. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo conventional cores were cut in the\r\nwell. Four FIT fluid samplings were attempted in the","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"182","properties":{"OBJECTID":182,"wlbNpdidWellbore":186,"wlbName":"25/11-4","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 25/11-4 was drilled ca 2.6 km south-south\r\nwest of the 25/11-1 Balder discovery well on the Utsira High in the North Sea.\r\nThe objective was to define the continuity of oil bearing sands of Early Eocene\r\nage that were present in 25/11-1 well.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 25/11-4 was spudded with\r\nthe vessel Glomar Grand Isle on 15 October 1970 and drilled to TD at 1896 m in\r\nthe Early Paleocene Ekofisk Formation. Drilling operations were normal down to 963\r\nm and at that depth problems with the Hydril necessitated pulling the riser and\r\nupper part of the B.O.P. stack. While drilling at 1753 m weather conditions\r\nhampered drilling and it was necessary to again pull the riser and upper part\r\nof the stack. After losing several days due to weather conditions the well was\r\ncompleted, however, during the midst of the logging operations, storm warnings\r\nmade it necessary to shorten the program and the planned velocity survey was\r\nnot made. Initial drilling from the seafloor to 179 m was with sea water and\r\ngel. Below 179 to a depth of 948 m, the mud system consisted of seawater,\r\nSpersene XP-20 Salinex. From 948 m to TD fresh water Spersene XP-20 mud was\r\nused.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well penetrated the Utsira Formation\r\nand several Skade Formation sand units and then entered a ca 500 m thick\r\nsection of shales belonging to the lower Hordaland Group before top Balder\r\nformation was encountered at 1695 m. The Balder Formation (Early Eocene) proved\r\nalmost void of reservoirs. It was all silty shale except a 4 foot sand section\r\nbetween 1740 and 1742 m. This sand had a good oil stain, bright yellow\r\nfluorescence and a bright yellow cut. The only massive reservoir present was\r\nthe Paleocene Hermod Formation sand from 1792 to 1816 m. This sand had no\r\nhydrocarbon","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"183","properties":{"OBJECTID":183,"wlbNpdidWellbore":187,"wlbName":"2/7-2","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 2/7-2 was drilled on the Grensen\r\nNose structural element in the Central Graben of the North Sea. The primary\r\ntargets for the well were Paleocene Sands and Danian Limestones; the secondary\r\ntargets were Late Cretaceous carbonates, Early Cretaceous sandstones, Jurassic\r\nsandstones, and possibly Permo-Triassic sandstone reservoirs.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 2/7-2 was spudded with the\r\nsemi-submersible installation Ocean Viking on 13 December 1970 and drilled to\r\nTD at 3964 m in the Early Permian Rotliegend Group. No significant technical\r\nproblem was encountered in the operations \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was drilled with sea water and\r\nviscous slugs down to 594 m and with sea water, lignosulphonate, and 2 - 7 %\r\noil from 594 m to TD. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well encountered the Late Paleocene\r\nBalder Formation at 2856 m, top Ekofisk Formation at 2966 m, and top Tor\r\nFormation at 3005 m. The Jurassic was encountered at 3862 m and consisted of 13\r\nm Mandal Formation. Total organic carbon content in the Mandal Formation was 7-9\r\n%, estimated to be of middle oil window maturity (vitrinite reflectance ca\r\n0.75). The Mandal Formation rested directly on sandstones of the Rotliegend\r\nGroup. Good oil shows decreasing to no shows were observed on cores 1 and 2 (3013.9\r\nto 3027.9 m) in the Tor Formation. Otherwise no significant shows or other\r\nhydrocarbon indications were reported from the well.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThree cores wore cut with 100% recovery. Cores\r\n1 and 2 were cut from 3013.9 to 3027.9 m, while core 3 was cut in basaltic rock\r\nat TD from 3955.1 to 3963.6 m. No wire line pressures or fluid samples were\r\ntaken.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp cl","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"184","properties":{"OBJECTID":184,"wlbNpdidWellbore":188,"wlbName":"2/5-2","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 2/5-2 was drilled as an appraisal\r\nwell on the 2/5-1 Tor Discovery in the southern Norwegian North Sea. The\r\nobjective was to evaluate the eastern part of the structure. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eAppraisal well 2/5-2 was spudded with the\r\njack-up installation M ærsk Explorer on 15 January 1971 and drilled to TD at\r\n3597 m in the Late Cretaceous Tor Formation. The well was drilled water based,\r\nbut with diesel addition below 1830 m.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well encountered top Paleocene\r\n(Balder Formation at 2978 m, top Danian chalk (Ekofisk Formation) at 3118 m,\r\nand top Late Cretaceous chalk (Tor Formation) at 3360 m. Commercial quantities\r\nof hydrocarbons were encountered in the Ekofisk Formation where a total of\r\napproximately 57 m net pay out of a gross section of 244 m was found. This was\r\na significant reduction from the 89 m net pay in the 2/5-1 discovery well.\r\nFurthermore, the water saturation in Ekofisk was higher in 2/5-2 compared to\r\n2/5-1 (41% and 22%, respectively).\u003c/p\u003e\r\n\r\n\u003cp\u003eFive conventional cores were cut in the\r\nintervals 3120 - 3188 m and 3235 - 3311 m in the Ekofisk Formation. No wire\r\nline fluid samples were taken.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 20\r\nApril 1971 as a an oil appraisal.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eSix drill stem tests were carried out:\r\nDST 1 in Late Cretaceous chalk (Tor Formation), DST 2 in the Late Cretaceous/\r\nDanian boundary, and DST 3 - 6 in Danian chalk (Ekofisk Formation). The\r\nfollowing results are after acidization: \u003c/p\u003e\r\n\r\n\u003cp\u003eDST 1 in the interval 3511 to 3513 m\r\nflowed minor quantities of slightly oil-cut mud. \u003c/p\u003e\r\n\r\n\u003cp\u003eDST 2 at 3350 - 3361 m flowed 165 Sm3, 34\r\nm3 water, and 39077 Sm3 gas /day on 64/64" + 32/64" choke. The oil\r\ngravity was 39 deg API and the GOR was 237 Sm3/Sm3. \u003c/p\u003e\r\n\r\n\u003cp\u003eDST 3 at 3299 - 3314 m flowed 629 Sm3 oil\r\nand 159900 Sm3 gas /day on a 23/64" choke. The oil gravity was 40.5 deg\r\nAPI and the GOR was 254 Sm3/Sm3. Maximum bottom hole temperature recorded in\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"185","properties":{"OBJECTID":185,"wlbNpdidWellbore":189,"wlbName":"16/5-1","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 16/5-1 is located on the Utsira High\r\nin the North Sea. The main target of the 16/5-1 well ("Vali") was a\r\npinch-out of Paleocene sands on a seismic monoclinal. The interest in this trap\r\nwas emphasized by oil-shows in Paleocene sands in surrounding wells.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 16/5-1 was spudded with the\r\nsemi-submersible installation Pentagone 81 on 17 January 1971 and drilled to TD\r\nat 1943 m in granitic basement rocks. The well was drilled using seawater-based\r\nmud.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe Paleocene sands, which were the main\r\nobjective of the Vali well, were not present. A thin Cretaceous series was\r\nfound directly overlaying Caledonian basement rocks. From 1923 m to TD the well\r\npenetrated migmatitic granite, highly fractured and slightly weathered down to\r\n1940 m. No shows were recorded, only background gas of C1 from1% to 3 % while\r\ndrilling the tertiary series. The only reservoirs encountered in Vali well were\r\n164 m net sand in the sand-shale sequence in the Utsira Formation from 754 m to\r\n1012 m. These sands, very fine to medium and shelly, have very high porosity,\r\nmore than 32 %. However, they are not sufficiently buried to form a trap and\r\nthey were water wet. Two cores were cut: the first from 1573 to 1584 m in the\r\nSele and Lista Formations, 15 m below the cinerites, and the second from 1929\r\nto 1943 m in the basement rocks. No fluid samples were attempted. The well was\r\npermanently abandoned as a dry well on 8 February 1971.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was performed\u003c/p\u003e\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"186","properties":{"OBJECTID":186,"wlbNpdidWellbore":190,"wlbName":"25/1-1","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 25/1-1 was drilled in the middle of block\r\n25/1 in the Viking Graben, close to the UK border. Seismic surveys had defined\r\nstructural closure at several levels in Mesozoic and into lower Tertiary\r\nhorizons. At Paleocene level an "amoeboid" feature extending as much\r\nas 350 km2 with a vertical closure of 180 m was mapped. The primary objective\r\nof the well was to test the hydrocarbon potential of the Early Tertiary,\r\ninterpreted to be a deltaic sand build-up. Secondary objective was Jurassic\r\nsandstones.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well is Type Well for the Frigg, Svarte,\r\nBlodøks, Tryggvason, Kyrre, and Jorsalfare Formations.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 25/1-1 was spudded with the\r\nsemi-submersible installation Pentagone 81 on 30 March 1971 and drilled to TD\r\nat 4570 m in Middle Jurassic Hugin Formation. The well was drilled with a\r\nseawater/LFC mud system down to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eApart from sandy sections in the Nordland\r\nGroup, the lithology down to top Frigg Formation at 1836 m was mainly\r\nclaystones. The Frigg Formation sandstones had porosities in the range 30 to\r\n40% with permeabilities of several Darcy. It was hydrocarbon bearing with a\r\ngas/oil contact at 1972 m, and an oil/water contact at 1992 m. Further shows\r\nwere seen in a thin sand at 2470 m in the Lista Formation. An FIT sample recovered\r\na small amount of oil from this sand. Oil shows were also recorded on limestone\r\non core K5 in the Jorsalfare Formation. The Jurassic sequence penetrated by the\r\nwell was mainly shales of the Viking Group and only 10 m of Hugin Formation\r\nsand at TD. No shows were reported from the Hugin Formation.\u003c/p\u003e\r\n\r\n\u003cp\u003eSix conventional cores were cut. Cores K1\r\nto K3 were cut from 1868 to 1910 m in the Frigg Formation. K4 was cut from 2687\r\nto 2696 m in the lower Lista Formation, while K5 and K6 were cut from 2826 to\r\n2843 m and from 2993 m to 2997.5 m in the Jorsalfare Formation. Wire line fluid\r\nsampling was attempted at nine different depths. Hydrocarbon flu","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"187","properties":{"OBJECTID":187,"wlbNpdidWellbore":191,"wlbName":"7/9-1","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 7/9-1 is located on the Reke Fault\r\nZone between the Jæren High and the Sørvestlandet High. The objective of the\r\nwell was to test for hydrocarbons in Tertiary, Cretaceous, Jurassic, and\r\nTriassic reservoirs over a Zechstein salt well which showed 1300 feet of\r\nvertical closure over an area of about 65 square km at the base Tertiary level.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well is Reference Well for the Gassum\r\nand Fjerritslev formations.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 7/9-1 was spudded with the\r\njack-up installation Mærsk Explorer on 22 April 1970 and drilled to TD at 2931\r\nm in Zechstein salt. The well was spudded using a high viscosity gel-seawater\r\nmud. After drilling out of the 20" casing, which stuck at 242 m, the mud\r\nwas converted to a lignosulphonate-seawater. The 213 m of 26" rat hole\r\nleft below the 20" casing gave considerable trouble by acting as a build\r\nup area for large balls of gumbo, which collected there as 17 1/2" hole\r\nwas being made. An attempt to run electric logs at the 13 3/8" casing\r\npoint failed because of the fill at 442 m. Drilling detergent was used to\r\nreduce torque and drag and was successful in the upper part of the hole. The\r\ndiesel oil content of the mud was maintained between 4% and 7%. A deviation\r\nproblem arose in the 8 1/2" hole, starting around 2255 m where the angle\r\nwas 4.5°. It increased steadily and at 2723 m the last survey point was 5.5°.\r\nLight bit weight, high rotary speeds, and a bottom hole assembly usually\r\nsuccessful in dropping angle had no effect.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe Tertiary Paleocene Sands were not\r\ndeveloped over the structure. The other objectives, the Tertiary Danian\r\ncalceranites, the late Cretaceous Maastrichtian chalk, and the Middle Jurassic\r\nto Triassic sandstones, were confirmed, but were water bearing. During the\r\ndrilling of the Tertiary section to a depth of 1676 m shale gas from the\r\nsometimes richly organic shales maintained a high background between 0.5% and\r\n1% methane in ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"188","properties":{"OBJECTID":188,"wlbNpdidWellbore":192,"wlbName":"7/1-1","wlbHistory":"\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 7/1-1 was drilled on the J{ren High\r\nin the southern part of the North Sea, ca 8 km east of the UK border line.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 7/1-1 was spudded with the\r\nsemi-submersible installation Sedco 135 F on 3 July 1971 and drilled to TD at\r\n2808 m in the Triassic Skagerrak Formation. There were indications of shallow\r\ngas at 472 m, otherwise no significant problems were reported from the drilling\r\noperations. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well penetrated Quaternary and\r\nTertiary sediments with no significant sand development down to a depth of 2224\r\nm where Cretaceous Chalk of the Tor Formation was encountered. The Cretaceous\r\nsection continued down to 2661 m where the sandy Triassic Skagerrak Formation\r\nwas encountered. The well was dry and no shows were reported from the well other\r\nthan those originating from diesel added to the mud. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eTwo cores were cut, one from 2243.3 to\r\n2261.6 m in the Tor Formation and the other from 2451.2 to 2468.9 m in the Hod\r\nFormation. No wire line fluid samples were taken.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was permanently abandoned on 5\r\nAugust 1971 as a dry well.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eTesting\u003c/span\u003e\u003c/b\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo drill stem test was performed.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"189","properties":{"OBJECTID":189,"wlbNpdidWellbore":193,"wlbName":"8/12-1","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 8/12-1 is located in the Åsta\r\nGraben. It was drilled on a salt dome with about 122 m of vertical closure over\r\nan area of about 23 km2. The well was programmed to test all porous formations\r\nfrom the Miocene to the Triassic. The main objectives were the Palaeocene\r\nDanian, Middle Jurassic, and Triassic sections. Secondary possibilities were\r\nseen in the Oligocene - Miocene, Late Cretaceous, and Early Cretaceous. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe well is Reference Well for the Bryne\r\nFormation.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 8/12-1 was spudded with the\r\njack-up installation Maersk Explorer on 31 May 1971 and drilled to TD at 2875m\r\nin the Skagerrak Formation. Some difficulties were encountered with\r\nover-pressured shales from 853 m to 1113 m before setting 13-3/8" casing,\r\ncementing the 13-3/8" casing, and with lost returns immediately below the\r\n9-5/8" casing set at 1903 m. The well was drilled with a\r\nSeawater/gel/IMCO-RD-333 mud system with 3 % to 5 % oil. \u003c/p\u003e\r\n\r\n\u003cp\u003eMethane gas in quantities up to 12% was\r\nrecorded on the mud-gas detector during drilling of the Miocene and Oligocene\r\nclays. No significant reservoir sections were encountered in this section, and\r\nthe gas was most probably released directly from the richly organic clays. Two\r\nvery weak oil shows were obtained in the Middle Jurassic sandstones. In porous\r\nsandstones from core No.3, where one of these shows was observed, up to 9.4%\r\nresidual oil was measured. However, evaluation of the logs showed that all\r\nporous intervals penetrated were water bearing. The formation water in the\r\nMiddle Jurassic sandstones was calculated to have a salinity of 140,000 ppm\r\nNaCl. \u003c/p\u003e\r\n\r\n\u003cp\u003eThree conventional cores were cut in the\r\nintervals 6181 feet - 6237 feet (1884.0 m - 1901.0 m), 8811 feet - 8817 feet\r\n(2685.6 m - 2687.4 m), and 8919 feet - 8969 feet (2718.5 m to 2733.8 m). One\r\nfluid sample was taken on wire line at 2666 m. The tool was opened for 10 min\r\nand recovered 100 cc of salt water (55,","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"190","properties":{"OBJECTID":190,"wlbNpdidWellbore":194,"wlbName":"9/11-1","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 9/11-1 is situated in the Åsta\r\nGraben in the Danish-Norwegian Basin in the North Sea. The purpose of the well\r\nwas to test the hydrocarbon and reservoir potential of Triassic to basal\r\nTertiary sediments over a north-south elongated salt dome. The Jurassic -\r\nTriassic sandstones were the primary objective, with the Late Cretaceous -\r\nDanian carbonates and Palaeocene sandstones as secondary objectives.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well is Type Well for the Late\r\nPaleocene Fiskebank Formation\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 9/11-1 was spudded with the\r\nsemi-submersible installation Transworld 61 on 3 July 1971 and drilled to TD at\r\n2196 m in the Late Triassic Skagerrak Formation. The 26" section was first\r\ndrilled with a 17 1/2" bit to 412 m using gel/seawater mud. The hole was\r\nthen under-reamed to 26" to 411 m. The 26" bit was run in hole but\r\ncould not get past 119 m. When reaming was attempted, circulation was lost at\r\n127 m. The hole was then re-drilled to 412 m with a 17 1/2" bit and opened\r\nto 26" with no problems. The 20" casing was run and cemented at 378\r\nm. Eleven days were used on this interval and 700 bbl mud lost to seabed. The\r\nremaining well was drilled without significant problems. The well was drilled\r\nwith seawater and hi-vis pills to 127 m, with seawater and gel from 127 m to\r\n412 m, and with seawater / lignosulphonate (Spersene) and 1 -6 % diesel from\r\n412 m to TD. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe well drilled a thick\r\nTertiary-Quaternary section (approx. 1600 m), composed mainly of\r\nOligocene-Miocene brown-grey clays and Pliocene-Pleistocene grey sandy clays.\r\nThe Eocene (Lower part) is represented by green clays overlying varicoloured\r\nPaleocene clays without sands. There was a thin chalk, all of Late Cretaceous\r\nage (Tor Formation). No Danian was present. The Early Cretaceous was\r\nrepresented by a condensed sequence ranging from Valanginian to Aptian/Albian.\r\nFrom 1766 m to 1993 m there was a series of transitional Early Cret","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"191","properties":{"OBJECTID":191,"wlbNpdidWellbore":195,"wlbName":"25/1-2","wlbHistory":"\u003cht\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 25/1-2 was drilled to appraise the\r\n25/1-1 Frigg Discovery in the North Sea. The primary objective was to test the Eocene\r\nFrigg Formation sandstone.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 25/1-2 was spudded with the semi-submersible\r\ninstallation Pentagone 81 on 22 July 1971 and drilled to 1159 m where the tool\r\nstuck. The well was then sidetracked from 719 m and drilled to TD at 2772 m in\r\nthe Late Cretaceous Shetland Group. The well was drilled with a water-LFC mud\r\nsystem. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe Frigg Formation sandstone was\r\nencountered at 1948 m. The Frigg sandstones were gas filled down to the gas/oil\r\ncontact at 1974 and oil filled to the oil/water contact at 1983 m. Thin\r\nsandstones and sandstone stringers in the interval 2441 to 2513 m had good oil\r\nshows.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo cores were cut. FIT fluid samples were\r\ntaken at 1984 m (oil and gas), 1986.3 m (oil, filtrate and gas), 1993.5 m (oil,\r\nfiltrate and gas), 2503 m (filtrate and trace oil), and 2508.5 m (filtrate and\r\ntrace oil), \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was permanently abandoned on 25 August\r\nas an oil and gas appraisal well.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eTesting\u003c/span\u003e\u003c/b\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo drill stem test was performed. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"192","properties":{"OBJECTID":192,"wlbNpdidWellbore":196,"wlbName":"2/4-7","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 2/4-7 was drilled on a structure ca\r\nsix km west off the Ekofisk discovery. The objective of the well was to test\r\nthe Danian limestone with estimated 200 m gross / 120 m net pay, and the Late\r\nCretaceous limestone with estimated 60 m gross / 15 m net pay. These Formations\r\nhad proved oil productive in the other wells on the Tor structure. Secondary\r\nobjective was possible Paleocene sand in the interval 3020 - 3140 m. Planned\r\ndepth was 3414 m (11200 ft).\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eAppraisal well 2/4-7 was spudded with the\r\njack-up installation M ærsk Explorer on and drilled to TD at 3493 m in the Late\r\nCretaceous Tor Formation. The drill pipe stuck at 3405 m, but was freed after\r\nseven hours working. The well was drilled with seawater and gel down to 555 m\r\nand with seawater/drill aid and 2 - 5% diesel from 555 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eTop Paleocene (Balder Formation) was\r\nencountered at 3048 m. The Paleocene contained only minor, thin sand beds. The\r\nchalk group came in with the Ekofisk Formation at 3175 m and the Tor Formation\r\nat 3304 m. Fair shows were recorded on cores in the top 2 m of the Ekofisk\r\nFormation, otherwise Ekofisk only had scattered shows. Fair to good shows were\r\nagain recorded in the Tor Formation, from the top and down to 3332 m. Below this\r\ndepth shows were reported as spotty, on fracture plains. Oil was confirmed by\r\ntesting in the top 24 m of the Tor Formation. The test in top Ekofisk gave only\r\nwater with a trace of gas. Thirteen cores were cut in the well, recovering a\r\ntotal of 164 m core. Core 1 to 9 were cut throughout the Ekofisk Formation, the\r\nrest were cut in the upper part of the Tor Formation. Core depths were reported\r\nto be 4 - 5 m shallower than log depth for all cores except core 5, which need\r\nto be shifted only + 1 m. No wire line fluid samples were taken.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 18\r\nOctober as an oil appraisal.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eSeven drill stem tests were carried out\r\nthrough per","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"193","properties":{"OBJECTID":193,"wlbNpdidWellbore":197,"wlbName":"15/6-1","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 15/6-1 is located ca 5 km north of\r\nthe Sleipner Field. The primary objective of the well was Eocene sands.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 15/6-1 was spudded with the drill\r\nvessel Glomar Grand Isle on 7 August 1971and drilled to TD at 1679 m in Eocene\r\nsediments of the Hordaland Group. Initial drilling from the sea floor to 384 m was\r\nwith sea water and gel. Below 384 m to a depth of 1247 m the mud system\r\nconsisted of sea water and Spersene XP-20 Salinex with drilling detergent. From\r\n1247 m to TD a fresh water Spersene XP-20 system was used. Due to problems with\r\nthe casing seal assembly the well was abandoned without reaching its target.\r\nThe vessel vas moved approximately 335 m east and a replacement hole (15/6-2) was\r\ndrilled.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe only reservoir penetrated was a thick\r\nMiocene sand section (the Utsira Formation) between 768 and 996 m. No hydrocarbon\r\nshows were encountered.\u003c/p\u003e\r\n\r\n\u003cp\u003eNo cores were cut and no wire line fluid\r\nsamples were taken.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 8 September 1971 as a junk well.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was performed.\u003c/p\u003e\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"194","properties":{"OBJECTID":194,"wlbNpdidWellbore":198,"wlbName":"2/3-3","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 2/3-3 is located east of the\r\nSteinbit Terrace on the Sørvestlandet High. The main targets for the well were\r\nDanian limestones, Jurassic sands, and Oligocene sands. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 2/3-3 was spudded with the\r\nJack-up installation Ocean Tide on 8 October 1971 and drilled to TD at in Late\r\nPermian Zechstein salt. Operations went without major problems except for some\r\ndelays due to bad weather (on 17 November with winds in excess of 40 m/s and\r\nseas up to 17 m). The well was drilled with Bentonite and salt gel down to 269\r\nm and with Spersene mud with 2% - 6.5% diesel from 269 m to TD. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe well drilled a thick\r\nTertiary/Quaternary section, mainly represented by grey sandy clays of Pliocene\r\nand Pleistocene age and by brown clays and mudstones of Oligocene to Miocene\r\nage. The Paleocene and Early Eocene consisted of varicoloured clays. No\r\npotential reservoirs (sands, sandstones and limestones) were found in the\r\nTertiary.\u003c/p\u003e\r\n\r\n\u003cp\u003eA moderate thickness (235 m) of Chalk was\r\npenetrated. The top 41 m was of Danian age (Ekofisk Formation, the remainder\r\nwas of Santonian-Maastrichtian age (Tor and Hod Formations). One hundred and\r\nforty seven meters of Early Cretaceous rested on Kimmeridgian shales. From the\r\nbase of the Kimmeridgian downwards, the section was poorly fossiliferous and\r\nonly tentatively dated. The only shows observed were elevated methane readings\r\nin sand stringers in the interval 400 m to 900 m and in shales below this\r\ndepth. No liquid hydrocarbons were observed in any part of the well. No cores\r\nwere cut and no fluid samples taken. The well was abandoned as dry on 20\r\nNovember 1971.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was performed\u003c/p\u003e\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"195","properties":{"OBJECTID":195,"wlbNpdidWellbore":199,"wlbName":"15/12-3","wlbHistory":"\r\n\r\n\u003cp\u003eWell 15/12-3 is located in the South\r\nViking Graben in the North Sea, south of the Sleipner Øst Field. The primary objective\r\nof the well was to test possible hydrocarbons in late Jurassic sand. This sand\r\nwas proven in 15/12-2. Secondary objectives were Danian and Rotliegendes sands.\r\nMinor Danian sand beds were proved in 15/12-1, and further west on the UK side oil was produced from Palaeocene sands on the Maureen Field. The well should be\r\ndrilled through ca 1100 m of prognosed salt and 100 m into the Rotliegendes or\r\nto a total depth of 4900 m. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 15/12-3 was spudded with the\r\nsemi-submersible installation Nordraug on 21 June 1980 and drilled to TD at\r\n4450 m in Early Permian Rotliegendes sandstone. After setting the 13 3/8"\r\ncasing the rig crew went on strike from 20 July to 14 August. While drilling 12\r\n1/4" hole with salt saturated mud the bottom hole assembly got stuck at\r\n2715 m when pulling out of the hole. Eleven days were spent working on the fish\r\nbefore the hole was eventually sidetracked from 2488 m. The well was drilled\r\nwith seawater/bentonite/lignosulphonate mud down to 2185 m, with salt saturated\r\npolymer mud from 2185 m to 3361 m, and with oil based mud (Oilfaze) from 3361 m\r\nto TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe primary objective, Jurassic sandstone,\r\nwas only a few meter thick. The sand was found deeper and was thinner than\r\nexpected. The well proved no sand in Palaeocene. The other secondary objective,\r\nRotliegendes sandstone, was highly interbedded with shale. None of the sands had\r\nshows of hydrocarbons. \u003c/p\u003e\r\n\r\n\u003cp\u003eOne core was cut from 3256 to 3263 m in\r\nthe Zechstein Group above the salt. A second core was cut near final TD in the\r\nRotliegendes Group from 4424 to 4433 m. No wire line fluid samples were taken.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 22\r\nDecember 1980 as a dry well.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was performed.\u003c/p\u003e\r\n\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"196","properties":{"OBJECTID":196,"wlbNpdidWellbore":200,"wlbName":"2/7-17","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 2/7-17 was drilled on a low\r\nrelief structure to the southwest of the Eldfisk Field in the southern\r\nNorwegian North Sea. The primary objective was to test the Danian - Late\r\nCretaceous limestone and chalk. Secondary objectives were the Late Cretaceous\r\nand Jurassic where irregular and lens-shaped structures on the seismic records\r\nwere interpreted as possible sandstones with stratigraphically trapped\r\nhydrocarbons.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 2/7-17 was spudded with the semi-submersible\r\ninstallation Borgsten Dolphin on 24 June 1980 and drilled to 1600 m in Miocene\r\nsediments. After setting the 13 3/8" casing the casing collapsed, forcing\r\nabandonment of the well. The objectives were not reached. The well was drilled\r\nwith seawater, native solids, gel, and bentonite.\u003c/p\u003e\r\n\r\n\u003cp\u003eNo reservoir sections or hydrocarbon\r\nindications were reported in the penetrated sediment column.\u003c/p\u003e\r\n\r\n\u003cp\u003eNo cores were cut and no wire line fluid\r\nsamples taken.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 12\r\nJuly 1980 as a junk well.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was performed\u003c/p\u003e\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"197","properties":{"OBJECTID":197,"wlbNpdidWellbore":201,"wlbName":"25/4-5","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 25/4-5 was drilled ca 1 km SW of the\r\n25/4-1 Heimdal Discovery well. The primary objective was to test the Vestland Group and\r\nthe Statfjord Formation on a down-thrown panel west of the high drilled by the\r\n25/4-1 well, which found several hydrocarbon bearing Jurassic levels in\r\naddition to the main Heimdal Discovery. The secondary objective was to appraise\r\nthe gas-bearing section in the Paleocene Heimdal Formation.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 25/4-5 was spudded with the\r\nsemi-submersible installation Dyvi Alpha on 26 June 1980 and drilled to TD at\r\n4355 m in the Triassic Smith Bank Formation. Operations were interrupted by a\r\nstrike that led to 4.5 days down time.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe Heimdal reservoir was found at 2150 m\r\nwith gas down to a GOC at 2172 m and a 7 m oil column down to the oil-water\r\ncontact at 2179 m. Drill with 8 1/2" bit from 3600 m to 4198.5 m When\r\nrunning in hole in the 8 1/2" section the bit stuck at 4174. The hole was\r\nthen backed off to 3891 m and a technical sidetrack was made from 3769 m.\u003c/p\u003e\r\n\r\n\u003cp\u003eA 128 m thick Vestland Group was\r\npenetrated from 3692 m to 3820 m. The Hugin and Sleipner formations were found water bearing with\r\nresidual hydrocarbons with the exception of a thin oil bearing interval from\r\n3777.5 m to 3781.5 m. RFT sampling over this zone indicated a water gradient,\r\nbut an RFT fluid sample recovered both oil (0.25 l) and gas (139 l). \u003c/p\u003e\r\n\r\n\u003cp\u003eThe Statfjord was encountered at 3949 m\r\nand was 178 m thick. It contained sandstones in the upper 50 m and in the\r\ninterval from 4064 to 4098 m. The upper interval could be interpreted as\r\nhydrocarbon bearing. Direct fluorescence (yellow) and cuts (yellow -pale blue)\r\nwere observed on the cores from this formation, and migrated hydrocarbons were\r\nalso found by post-well organic geochemical analyses. Tests (DST and RFT) recovered\r\nonly water. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe triassic Group contained a 50 meters\r\nsandstone reservoir, which was drilled with good shows. The tests","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"198","properties":{"OBJECTID":198,"wlbNpdidWellbore":202,"wlbName":"6507/12-1","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 6507/12-1 was the first well\r\nto be drilled offshore Mid-Norway. It was drilled to test the stratigraphic\r\nsequence between seabed and at least 500 m below "reflector E" as\r\ndefined in the licence agreement. The primary target was a mapped Intra\r\nJurassic seismic reflector at a depth of approximately 2575 m. This reflector\r\nwas interpreted to be associated with a Middle to Early Jurassic sandstone\r\nsequence. The secondary target was represented by possible sandstone sequences\r\nbetween the mapped Base Cretaceous reflector and the Intra Jurassic reflector.\r\nThirdly there was a small vertical closure in the basal part of the Tertiary\r\nsequence that could have prospective interest.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well is Type Well for the Båt Group,\r\nthe Tare Formation and the Naust Formation. It is Reference Well for the Fangst\r\nGroup.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was spudded with the\r\nsemi-submersible installation Byford Dolphin on 1 July 1980 in a water depth of\r\n225 m, and drilled to a total depth of 3713 m in Late Triassic Red Beds. The\r\nwell was drilled with spud mud down to 778 m, with Gypsum PAC mud from 778 m to\r\n1448 m, and with Lignosulfonate/PAC mud from 1448 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well penetrated a section of 1105 m\r\nbelow reflector E and thus meets the requirement set in the work programme for\r\nlicence 059.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well encountered a Cenozoic sequence\r\nof 1679 m and the Tertiary succession was, at the time the well was drilled,\r\nsubdivided into lithostratigraphic units according to Deegan & Scull's\r\nnomenclature for the northern North Sea. The well proved a slightly thicker\r\nTertiary sequence than expected. The seismic leg interpreted to represent Base\r\nTertiary proved to be related to a tuff sequence (Tare Formation).\u003c/p\u003e\r\n\r\n\u003cp\u003eThe Top Cretaceous reflector was easily\r\ndetermined from acoustic and density logs. The base of the Cretaceous was\r\nencountered in the well at 2032 m. The prognosed depth was 1975 m. The\r\nCretaceous seque","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"199","properties":{"OBJECTID":199,"wlbNpdidWellbore":203,"wlbName":"30/3-2","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 30/3-2 is located ca 7 km north of the Oseberg Field in the Northern\r\n North Sea. The primary objective of the well was to\r\ntest sandstones belonging to the Brent and Dunlin group. Secondary objective\r\nwas sandstones in the Statfjord formation.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 30/3-2 was spudded with the\r\nsemi-submersible installation Deepsea Saga on 4 July 1980. Due to a strike beginning at July 13 drilling was temporary abandoned at 955 m in Miocene\r\nsediments of the Hordaland Group. The well was drilled with pre-hydrated gel.\u003c/p\u003e\r\n\r\n\u003cp\u003eNo cores were cut and no wire line fluid\r\nsamples were taken.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was suspended on 15 August 1980 and\r\nthe rig was taken to Bergen. The strike was terminated on 14 August and the rig\r\nwas back on location on August 29. The well was re-entered and operations\r\nresumed, now formally as a new well, 30/3-2 R.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was performed.\u003c/p\u003e\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"200","properties":{"OBJECTID":200,"wlbNpdidWellbore":204,"wlbName":"34/10-12","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 34/10-12 was drilled on Tampen Spur\r\nin the North Sea close to the western side of the Gullfaks Fault Block. The\r\nprimary objective of the well was to test sandstones of Middle Jurassic age.\r\nSecondary objectives were sandstones of Early Jurassic age.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 34/10-12 was spudded with\r\nthe semi-submersible installation Neptuno Nordraug on 16 July 1981 and drilled\r\nto TD at 2800 m in the Early Jurassic Statfjord Group. The well was drilled\r\nwith seawater and prehydrated Gel pills down to 298 m and with\r\ngel/lignosulphonate mud from 298 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe sandstones of both Middle and Early Jurassic\r\nage were water saturated. Shows were recorded on cuttings from claystones,\r\nlimestone and occasional thin sandstones from 1260 m in the Hordaland Group to\r\n1657 m in the Balder Formation. The Jurassic had only trace fluorescence in\r\nsandstone cuttings at 2094 to 2110 m in the Ness Formation, otherwise no trace\r\nof hydrocarbons were seen.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eOne core was cut from 2037 m to 2042.7 m\r\nin the Ness Formation. No wire line fluid samples were taken.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was permanently abandoned on 12\r\nSeptember as a dry well.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eTesting\u003c/span\u003e\u003c/b\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo drill stem test was performed.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"201","properties":{"OBJECTID":201,"wlbNpdidWellbore":205,"wlbName":"35/8-1","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 35/8-1 is located on the Marflo\r\nSpur, ca 30 km west of the Gjøa Field in the northern North Sea. The principal\r\nobjective of this well was to test the hydrocarbon potential of sandstones\r\nwithin the Jurassic section beneath the Late Cimmerian Unconformity.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 35/8-1 was spudded with the\r\nsemi-submersible installation Sedco-704 on 27 July 1980 and drilled to TD at 4345\r\nm in Late Triassic sediments of the Statfjord Formation. The well was drilled without\r\nsignificant technical problems, but two well kicks occurred .After penetrating\r\nthe Jurassic sand reservoir at 3516m a sudden rapid gas increase was noted, but\r\ndue to mechanical problems could not be measured. This increase was associated with\r\na quantity of reservoir fluids entering the borehole. During controlling of the\r\nkick, a large proportion of gas was vented and light low gravity yellowish oil\r\nrecovered from the mud. A second kick with formation fluids entering the well\r\nbore was taken after coring core no 3 at 3549.6 to 3567.1 m. The well was\r\ndrilled with seawater and viscous slugs down to 890 m, with\r\ngypsum/Lignosulphonate mud from 890 m to 2196 m, and with KCl/polymer mud from\r\n2196 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe top sections down to Top Rogaland\r\nGroup, Balder Formation at 1683 m contained a number of sands and sandy\r\nintervals. From top Rogaland and throughout the Cretaceous section down to top\r\nDraupne Formation at 3186 m the lithology was mainly claystone and limestone.\r\nThe heather Formation came in at 3200 m with two thin Intra-Heather Formation\r\nsandstones at 3219 and 3250 m. Heather Formation shale continued down to the\r\nBrent Group at 3516 m. Frequent sandstones were penetrated in the Brent and\r\nDunlin Groups, and in the Statfjord Formation. \u003c/span\u003e\u003c/p","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"202","properties":{"OBJECTID":202,"wlbNpdidWellbore":206,"wlbName":"2/7-18","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 2/7-18 was drilled as\r\nreplacement well for 2/7-17, which was junked for technical reasons. The well\r\nshould evaluate a low relief structure to the southwest of the Eldfisk Field in\r\nthe southern Norwegian North Sea. The primary objective was to test the Danian\r\n- Late Cretaceous limestone and chalk. Secondary objectives were the Late\r\nCretaceous and Jurassic where irregular and lens-shaped structures on the\r\nseismic records were interpreted as possible sandstones with stratigraphically\r\ntrapped hydrocarbons.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 2/7-18 was spudded with the\r\nsemi-submersible installation Borgsten Dolphin on 20 August 1980 and drilled to\r\n601 m in assumed Pliocene sediments. After setting the 20" casing,\r\nmechanical problems forced abandonment of the well. The objectives were not\r\nreached. The well was drilled with seawater.\u003c/p\u003e\r\n\r\n\u003cp\u003eNo logs were run, and no sample of any\r\nkind was collected.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 31\r\nAugust 1980 as a junk well.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was performed\u003c/p\u003e\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"203","properties":{"OBJECTID":203,"wlbNpdidWellbore":207,"wlbName":"15/5-3","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 15/5-3 was drilled in the Vilje\r\nSub-basin between the Enoch and the Gudrun fields in the North Sea. The primary\r\nobjective was to test possible sandstone reservoirs of Triassic age. A\r\nsecondary objective was to test the Middle Jurassic Sleipner Formation. The\r\nwell was planned to penetrate approximately 400 m into the Triassic and had a\r\nprojected total depth of 4200 m.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAfter two unsuccessful spuds, wildcat\r\nwell 15/5-3 was spudded with the semi-submersible installation Nortrym on 21\r\nAugust 1980 and drilled to TD at 5042 m in shale and sandstones of Late Permian\r\nage. Hole reaming was necessary in intervals below 2250 m, otherwise the well\r\nwas drilled without significant problems or incidents. The hole was good and\r\nvertical down to ca 3000 m. Below 3200 m the hole deviation increased to\r\nbetween 3° and 8°. The well was drilled with seawater and hi-vis sweeps down to\r\n615 m, with a seawater/Dextrid mud from 615 m to 2029 m, with\r\nseawater/polymer/Q.Broxin mud from 2029 m to 3834 m, and with a salt-saturated\r\nDextrid mud from 3834 to TD. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNone of the objective sandstone\r\nreservoirs were found in the well. The Draupne Formation was encountered at\r\n3665 m. After penetrating 135 m of Draupne shales, the well encountered 1050 m\r\nof Zechstein evaporites. At this point, it was decided to deepen the well\r\nfurther in order to explore the pre-salt rocks. Below these, undefined shales\r\nand thin sandstones of Late Permian age were found. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eTraces of oil in the mud was observed\r\nduring P&A - see below. Poor oil shows were recorded in thin limestone\r\nstringers at 2850 m, 2920, and in the interval 3355 to 3365 m. No shows were\r\nrecorded in the pre-Zechstein shales and sand se","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"204","properties":{"OBJECTID":204,"wlbNpdidWellbore":208,"wlbName":"31/2-4","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 31/2-4 is located some 10 km NNW of\r\nthe discovery well 31/2-1 in a separate fault compartment near the crest of the\r\nJurassic gas accumulation. This crestal area appeared also to coincide with the\r\nculminations of all deeper horizons that could be mapped. The well had two main\r\nobjectives. The first was to appraise the Jurassic gas accumulation in the\r\n31/2-1 Troll Discovery in a location with nearly maximum gross hydrocarbon\r\ncolumn. The well should test lateral variations in this reservoir. The second\r\nmajor objective was to explore deeper Triassic/Palaeozoic Formations. The well\r\nwould test possible hydrocarbon accumulations under the Late Jurassic Troll\r\nreservoir, explore possible pre-Jurassic source rocks, and provide geological\r\nages for deep horizons and thus improve the regional geological setting. \u003c/p\u003e\r\n\r\n\u003cp\u003eTD of the well was proposed to be 5000 m\r\nbelow sea level or in Palaeozoic formations whatever came first.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 31/2-4 was spudded with the\r\nsemi-submersible installation Borgny Dolphin on 1 September 1980 and drilled to\r\nTD at 815 m in the Hordaland Group. The well was drilled with seawater and\r\nhi-vis pills. After having set the 20" casing, the well was secured and\r\nsuspended on September 13 due to a farm out of the rig to Statoil. Statoil had\r\nrequested the Borgny Dolphin to be released to secure their well 34/10-10,\r\nwhich was blowing gas from a shallow gas zone. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was classified as a dry well.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was performed in the\r\nwell.\u003c/p\u003e\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"205","properties":{"OBJECTID":205,"wlbNpdidWellbore":210,"wlbName":"31/2-5","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 31/2-5 is located in the\r\nsouthern part of the oil province in the Troll West area, some 6 km west of the\r\ndiscovery well 31/2-1, in a downthrown fault block. The objectives of the well\r\nwere to test presence and nature of hydrocarbons in a structure west of the\r\nmain gas reservoir; to test lateral variation in reservoir characteristics\r\nwestwards; to investigate possible causes for the difference in flat spot\r\nappearance in this fault block; and to get a good geologic identification of\r\nthe various seismic reflectors for lateral extrapolation of well data. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eProblems were experienced during\r\npositioning and anchoring of semi-submersible installation West Venture for the\r\nwildcat well 31/2-5. After 6 days efforts the installation had to be\r\nrepositioned 25 m from the intended location and the anchors were successfully\r\nlaid out and tensioned. The well was spudded on 26 October 1980 and drilled to\r\nTD at 2532 m in the Triassic Hegre Group. The well was drilled with seawater\r\nand viscous pills down to 443 m, with gelled seawater from 443 m to 810 m, with\r\nKCl/polymer mud from 810 m to 1807 m, and with seawater/gel from 1807 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 31/2-5 confirmed that the Late\r\nJurassic Sognefjord Formation sandstone reservoir was well developed also in\r\nthe western part of the structure. A gas column was penetrated from 1536 m to\r\n1579 m (43 m), followed by a 21 m thick oil column down to an OWC at 1600 m.\r\nGood oil shows continued down to 1644.5 m. The GOC was found at the same depth\r\nas seen in the other wells in the area. The most interesting observation in\r\nthis well was the presence of the thick oil column below the gas, some 9 m\r\nthicker than seen in any of the other wells, and the oil was encountered in a\r\nsection of the reservoir with very good clean sand. It is yet too early to\r\nexplain the difference in oil thickness, and the importance of a thicker oil\r\ncolumn in a good sand will remain unknown until a full produc","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"206","properties":{"OBJECTID":206,"wlbNpdidWellbore":211,"wlbName":"34/10-11","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 34/10-11 was drilled on the Gullfaks\r\nDelta structure in the North Sea. The primary objective of the well was to test\r\nsandstones of Middle Jurassic age. Secondary objectives were sandstones of\r\nLower Jurassic age.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 34/10-11 was spudded with\r\nthe semi-submersible installation Ross Rig on 23 October 1980 and drilled to TD\r\nat 2155 m in Late Triassic sediments of the Lunde Formation. Bad weather caused\r\n511 hrs lost time (15.7% of total rig time). Significant lost time (509 hrs) was\r\ncaused also by malfunction and repairs of the BOP. The well was drilled with\r\nspud mud down to 463 m, with gel/lignosulphonate/seawater mud from 463 m to\r\n1100 m, with Gypsum/lignosulphonate/sweater mud from 1100 m to 1720 m, and with\r\ngel/lignosulphonate/seawater mud from 1720 m to TD. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eFirst oil shows were recorded from 1090 m\r\nto 1200 m, intermittent weak shows were seen from 1420 to 1495, and more or\r\nless continuous oil shows were recorded on limestone from 1660 m to top\r\nreservoir at 1868 m. The well proved oil in sandstones from top of the Early\r\nJurassic Amundsen Formation at 1868 down to the OWC at 2038 m in Late Triassic\r\nsediments of the Raude Formation. Below 2038 m shows were recorded down to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eSix cores were cut in the interval 1870 m\r\nto 1926.5 m in the Amundsen and Nansen formations. Two FIT fluid samplings were\r\nattempted. FIT 1 at 2081 m recovered 3 litres 35 °API oil and 7 litres of mud\r\nfiltrate in the 2 3/4 gallon chamber. The FIT 2 at 2051 m did not recover any\r\nfluids. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was permanently abandoned on 5\r\nmarch 1981 as a as an oil appraisal well on the Gullfaks field.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBo","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"207","properties":{"OBJECTID":207,"wlbNpdidWellbore":212,"wlbName":"34/10-20","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 34/10-20 was the first well drilled\r\non the Gamma structure south of Gullfaks Sør in the northern North Sea. The\r\nprimary objective was the Middle Jurassic Brent Group. Secondary objectives\r\nwere Early Cretaceous sandstones, the Cook Formation and the Statfjord Group.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 34/10-20 was spudded with\r\nthe semi-submersible installation Ross Isle on 23 December 1983 and drilled to\r\nTD at 3747 m in the Early Cretaceous Cromer Knoll Group. The well was plugged\r\nback and abandoned without reaching the targets. Engineering difficulties associated\r\nwith high fluid pressure and low formation integrity was the reason why the\r\nwell had to be abandoned. It was drilled with gel/seawater down to 1053 m, with\r\nKCl/polymer mud from 1053 m to 2990 m, and with lignosulphonate mud from 2990 m\r\nto TD. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was dry. Zones with weak shows,\r\nmostly on claystone cuttings, were recorded from 1860 m to 2050 m in the\r\nRogaland Group. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo cores were cut and no wire line fluid\r\nsamples were taken.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was permanently abandoned on 23\r\nApril 1984 as a junk well.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eTesting\u003c/span\u003e\u003c/b\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo drill stem test was performed.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"208","properties":{"OBJECTID":208,"wlbNpdidWellbore":213,"wlbName":"25/11-9","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-US\u003eWell 25/11-9 was drilled ca km west-south\r\nwest of the 25/11-1 Balder discovery well on the Utsira High in the North Sea.\r\nThe objective was to establish the presence of a thick accumulation of oil sand\r\nin the southern part of the Balder Field, and to confirm the reservoir quality\r\nof Lobe 8 penetrated in the 25/11-5 well. The top of the reservoir was\r\nanticipated to be at 1688 m subsea.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 25/11-9 was spudded with\r\nthe semi-submersible installation Norskald on 4 November 1980 and drilled to TD\r\nat 1910 m in the Late Cretaceous Tor Formation. The well was drilled with Seawater/Gel/Lignosulphonate.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well penetrated the Utsira Formation\r\nand several Skade Formation sands and then penetrated a ca 560 m thick section\r\nof shale/mudstone/siltstone belonging to the lower Hordaland Group before top\r\nBalder Formation was encountered at 1670 m. Drilling revealed two oil sand\r\nzones, one of Eocene age between 1708.5 m and 1742 m (Intra Balder Formation\r\nsand), the second of Paleocene age (Hermod Formation) between 1781 m and 1785 m,\r\nwhich is the Balder Field oil-water contact. A few thin sands in the upper\r\nBalder Formation from 1671 m to1694 m also appeared to be oil bearing. A second\r\nHermod Formation from 1789 to 1818 m was water wet with some weak shows. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eFour conventional cores were attempted in\r\nthe interval 1718 to 1744 m in the Intra Balder Formation Sandstone, but only\r\n3.5 m from the first and 1.5 m from the last core was retrieved. No wire line\r\nfluid samples were taken.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was permanently abandoned on 7\r\nDecember 1980 as an oil appraisal well.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003e","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"209","properties":{"OBJECTID":209,"wlbNpdidWellbore":214,"wlbName":"31/4-4","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 31/4-4 is located on the\r\nLomre Terrace north of the Brage Field and east of the Oseberg Field. The\r\nprimary objective of the well was to test possible sandstone reservoirs of\r\nCretaceous age. The secondary objective was to test sandstone reservoirs of\r\nLate Jurassic age, anticipated to be Intra Heather Formation sands.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well is Reference Well for the Etive,\r\n Ness, and Tarbert Formations of the Brent Group.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 31/4-4 was spudded with the semi-submersible\r\ninstallation Nortrym on 17 December 1980 and drilled to TD at 3150 m in Early\r\nJurassic sediments of the Statfjord Formation. The well was drilled with\r\nseawater and viscous gel down to 900 m and with KCl / polymer mud from 900 m to\r\nTD.\u003c/p\u003e\r\n\r\n\u003cp\u003eNo reservoir sands of Cretaceous age were\r\nencountered in the well. Poor shows were reported from two limestone stringers\r\nand a thin, tight sandstone stringer of Late Cretaceous (Maastrichtian and Late\r\nCampanian) age. A Late Jurassic "Intra Heather Sand I" (Sognefjord\r\nFormation) was encountered at 2363 m with a gross thickness of 39 m. The net\r\nsand interval was 24 m and consisted of fine-grained to very fine-grained\r\nargillaceous, micaceous sandstone. Average porosity was calculated to 16 %.\r\nEighty-nine percent water saturation was calculated for this sand indicating\r\nthat poor oil shows encountered while drilling the interval, were residual. A\r\nsecond "Intra Heather Sand II" (Fensfjord Formation) was penetrated\r\nat 2482 m with a gross thickness of 45 m. The sand was water bearing without\r\nshows. The lithology was similar to the upper sand. The other reservoir\r\nsequences encountered in the well, sandstones in the Middle Jurassic Brent\r\nFormation, the Early Jurassic Cook Formation, and the Statfjord Formation, were\r\nalso water bearing. The gross sand thicknesses of these were 118 m, 21m and\r\n67m, respectively. \u003c/p\u003e\r\n\r\n\u003cp\u003eA single conventional core was cut\r\nbetween 2490m and 250 8m, near the","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"210","properties":{"OBJECTID":210,"wlbNpdidWellbore":215,"wlbName":"34/2-2","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eExploration well 34/2-2 is located a\r\nnorthwestern part of the Tampen Spur area. It was intended to be the first well\r\nto test the reflections below the Base Cretaceous (Kimmeridgian) Unconformity\r\non a seismically defined, northerly trending west-northwest dipping fault\r\nblock. The well was located near the apex of the structure at the Base\r\nCretaceous level, but down-dip with respect to deeper stratigraphy. Primary\r\ntargets were the Middle Jurassic Brent Formation and the Early Jurassic/Triassic\r\nStatfjord Formation. Secondary targets were possible Early Tertiary and Late\r\nJurassic sandstones. Planned TD was 4300 m Sub Sea. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 34/2-2 was spudded with the\r\nsemi-submersible installation Sedco 703 on 27 November 1980. Drilling proceeded\r\nto 513 m\u00A0 where bad weather caused a three days wait-on-weather interruption.\r\nResuming drilling the drill string parted and was lost in the hole. Fishing was\r\nattempted but the fish could not be retrieved. The well bore was technically\r\nsuspended on 12 December 1980 as a dry well. Operations were resumed the same\r\nday as the re-entry 34/2-2 R.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was performed.\u003c/p\u003e\r\n\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"211","properties":{"OBJECTID":211,"wlbNpdidWellbore":216,"wlbName":"30/7-8","wlbHistory":"\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 30/7-8 was drilled in the Norwegian\r\npart of the Shetland Basin. The primary objective was to test the hydrocarbon\r\npotential in the Middle Jurassic Brent group, which had previously proved gas\r\nand condensate bearing in wells 30/4-2 and 30/7-6. The Early Jurassic Cook\r\nFormation and Statfjord Group were secondary targets. The planned TD was 4600 m\r\nin the Triassic Red Beds.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 30/7-8 was spudded with\r\nthe semi-submersible installation\u00A0 Treasure Seeker on 19 November 1980 and\r\ndrilled to 4287 m in the Middle Jurassic Brent Group . The drill pipe became\r\ndifferentially stuck at 4069 m. After unsuccessful fishing, the well was\r\nsuspended with top of the fish at 4058 m, and 4287 m became official TD for the\r\nwell. The well was drilled with seawater and hi-vis pills down to 215 m, with\r\nwater based "lost circulation mud" from 215 m to 962 m, with\r\ngypsum/lignosulphonate mud from 962 m to 2648 m, with a bentonite/lignosulfonate/lignite\r\nmud type from 2648 m to TD. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eFrequent traces of oil shows were\r\ndescribed in many intervals from 1820 m and down to well TD. Most of the shows occurred\r\nin limestone stringers and were rated poor. The primary target Middle Jurassic\r\n(Bathonian-Bajocian) Brent Group reservoir was encountered at 4066 m. The shows\r\nin the Brent Group sandstones were rated good.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eFive cores were cut in the well. One was\r\ncut in the Draupne Formation from 3888.5 m, while the other four were cut in\r\nthe Brent Group reservoir section from 4082.3 m to 4129.3 m. No fluid sample\r\nwas taken.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was suspended on 4 April 1980 as\r\na gas/condensate appraisal well. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyTex","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"212","properties":{"OBJECTID":212,"wlbNpdidWellbore":217,"wlbName":"25/10-4","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThis well was drilled in two phases, a\r\nprimary well bore 25/10-4, and a re-entry well bore 25/10-4 R. The well was\r\ndrilled in the western part of the Balder Field in the North Sea. The primary\r\nobjective was to establish the presence of a thick accumulation of Paleocene\r\noil sand, and evaluate sand-shale distribution and reservoir quality. The top\r\nof the reservoir was anticipated to be at 1698 m subsea. As a secondary\r\nhigh-risk objective, the well was to be drilled to 2700 m to test for the\r\npresence of hydrocarbons in the Permian. This test was necessary as any\r\nhydrocarbons present could critically affect the design and location of a\r\npossible production platform.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eAppraisal well 25/10-4 was spudded with\r\nthe semi-submersible installation Glomar Biscay II on 8 December 1980 and\r\ndrilled to TD at 2348 m in the Late Permian Zechstein Group where the well was\r\nsuspended due at 18 January 1981 due to a pressing need for the rig to drill\r\nother Balder Field delineation wells, combined with unexpected delays in the\r\n25/10-4 well progress as a result of lost circulation. The re-entry commenced\r\non 29 May 1981 and deepened the well to 2550 m in a massive unconsolidated sand\r\nof Permian/ Carboniferous age. The top hole down to 30" casing depth at\r\n214 m was drilled with seawater. Below 214 m the well, including the re-entry\r\nwell, was drilled with seawater/gels/lignosulphonate.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe main oil sand of Paleocene age was\r\nencountered between 1759.5 m and 1784.0 m. The net oil sand was 22 m thick. The\r\nTriassic section had several thin and oil-bearing sandstones not detected\r\nbefore in the area. A wire line FIT in one of these sands proved live oil. In\r\ntotal these sandstones made up 21 m net sand but the accumulation was\r\nconsidered insignificant. Cuttings from 2130 m (Early Jurassic) through Permian\r\nZechstein and the upper part of the Permian/Carboniferous unconsolidated\r\nsandstone contained traces/shows of hydrocarbons.\u003c/p\u003e","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"213","properties":{"OBJECTID":213,"wlbNpdidWellbore":218,"wlbName":"15/9-7","wlbHistory":"\u003chtml\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 15/9-7 was drilled as an appraisal\r\nwell on the south part of the Sleipner Vest Field in the North Sea. The primary\r\nobjective was to test for hydrocarbons in Callovian age sandstones in the\r\nEpsilon structure.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 15/9-7 was spudded with\r\nthe semi-submersible installation Nordraug on 26 December 1980 and drilled to\r\nTD at 3776 m in the Middle Jurassic Sleipner Formation. A total of 20 days was\r\nspent on waiting on weather. The phase of running BOP after cemented 20"\r\ncasing took 15 days due to several broken guide wires combined with bad\r\nweather. The well was drilled with spud mud down to 465 m, with gypsum/polymer\r\nmud from 465 m to 2823 m, and with gel/lignosulphonate/Drispac mud from 2823 m\r\nto TD. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe primary target Hugin Formation was\r\npenetrated at 3519 m and proved to hold gas and condensate down to a true gas/water\r\ncontact at 3673 m based on RFT gas gradients. The gross reservoir thickness was\r\n185 m (3519 to 3704 m) with a net pay of 83 m with 18% porosity and 12 % water\r\nsaturation. There were no oil shows above top Hugin reservoir level. Oil shows\r\nwere described on the cores from the reservoir and on cuttings down to 3677 m.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eA total of 156 m core was recovered in 12\r\ncores from the interval 3516 to 3671 m. The core-log depth shift was\r\nsignificant for all cores: from +6.0 to +9.1 meter, the largest shifts are for\r\nthe deepest cores. Segregated RFT fluid samples were taken at 3560 m (gas, mud\r\nfiltrate and condensate), 3603 m (gas, mud filtrate and condensate), 3658.5 m\r\n(gas, mud filtrate and condensate +dark oil emulsion), 3687 m (mud filtrate,\r\nformation water and minor gas), and 3672.2 m (mud filtrate and water). \u003c/span\u003e\u003c/p\u003e\r\n\r","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"214","properties":{"OBJECTID":214,"wlbNpdidWellbore":219,"wlbName":"35/3-4","wlbHistory":"\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat wells 35/3-3 and 35/3-4 were\r\ndrilled in the Norwegian sector of the North Sea approximately 50 km west of\r\nMålØy, Norway. The primary target was to test the possible extension of Lower\r\nCretaceous sandstones to the east of those encountered in wells 35/3-1 and\r\n35/3-2. A stratigraphic trap was thought to exist in these sandstones. A\r\nsecondary target was possible sandstones of Early Jurassic age with a possible\r\npinch-out trap.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 35/3-3 was spudded with the\r\nsemi-submersible installation Byford Dolphin on 30 October 1980. It was drilled\r\nand logged to 900 m, then junked because of technical problems running the\r\n20" casing. The rig was moved about 20 meters, and the well was respudded\r\nas 35/3-4.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 35/3-4 was spudded with the\r\nsemi-submersible installation Byford Dolphin on 30 November 1980 and drilled to\r\nTD at 4089 m in Basement rocks (Caledonian age). A sidetrack was drilled from\r\n3768 m. The well was drilled with seawater and gel down to 457m, with seawater/gel/lignosulfonate\r\nfrom 457 m to 879 m, with lignosulfonate/gypsum/gel mud from 879 m to 2388 m,\r\nand with gel/lignosulfonate/PAC mud from 2388 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well penetrated strata from Tertiary\r\nthrough Jurassic before reaching basement rocks-of Caledonian age. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eHydrocarbon shows were encountered in\r\nLower Cretaceous and Lower-Middle Jurassic sand. The Lower Cretaceous sediments\r\nwere interpreted as submarine fans. RFT measurements in Lower Cretaceous\r\nindicate an upper zone with a gas gradient of 0.4 psi/m, and a deeper zone with\r\na water gradient of 1,54 psi/m. There seem to be no pressure communication\r\nbetween these two zones. Log evaluation in","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"215","properties":{"OBJECTID":215,"wlbNpdidWellbore":220,"wlbName":"3/7-2","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 3/7-2 was drilled on a structure\r\nlocated across blocks 3/4 (Amoco Group) and 3/7 (Petronord Group. The primary\r\ntargets were: Tertiary sands found gas bearing in well 2/3-1; Danian/Late\r\nCretaceous limestone (chalk) hydrocarbon bearing in the Ekofisk area and in the\r\nDanish well Lulu 1; Middle Jurassic sandstones which were hydrocarbon bearing\r\nin well 2/6-2; and Rotliegendes sandstones. The TD was planned into the\r\nCarboniferous in order to establish the source potential of this formation.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 3/7-2 was spudded with the\r\nsemi-submersible installation Dyvi Alpha on 30 March and drilled to TD at 4330\r\nm in the Early Permian Rotliegendes Group. A drilling break occurred at 2534 m.\r\nFlow check at 2553 m showed a weak flow, which was controlled by raising the\r\nmud weight to 1.46 sg. Drilling resumed and was stopped at 2563 m for logging.\r\nThree days were necessary to run the electric logs because of continuous slight\r\nflow. Deviation problems were experienced in the salt. The deviation reached a\r\nmaximum of 9 1/2 deg at 3659 m then was reduced to 2 1/2 deg at 4004 m. The\r\nwell was drilled with a lignosulphonate mud from 2563 m to 3027 m. Below the 9\r\n5/8" casing shoe at 3012 m the mud was displaced to a salt saturated mud.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe Eocene/Oligocene sands were found\r\nmissing. Only 8 meters of sand were encountered in the Paleocene. The chalk was\r\ntight and water bearing. The Jurassic sandstones were not as developed as\r\nprognosed, and they were water bearing. No sandstones were encountered in the\r\nRotliegendes Group, which consisted of an upper shale and a lower volcanic\r\nunit. Carboniferous sediments were not penetrated. All the targets above the\r\nsalt were found water bearing while no reservoir was encountered below 4166 m (base\r\nsalt, F horizon). Prognosed stratigraphy at base Cretaceous and below was in\r\nerror. Base Cretaceous was encountered 115 m higher than prognosed, top salt\r\nwas 209 m higher than prognosed,","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"216","properties":{"OBJECTID":216,"wlbNpdidWellbore":221,"wlbName":"34/10-21","wlbHistory":"\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 34/10-21 was the third well drilled\r\non the Gullfaks South structure in the Tampen Spur area in the northern North\r\nSea. The objective was to test for possible hydrocarbon accumulations and for a\r\npossible extension of reserves in the Gullfaks South field. Targets included\r\nthe Brent, Cook and Statfjord Sandstones and possible sand accumulations in the\r\nEarly Cretaceous.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 34/10-21 was spudded with\r\nthe semi-submersible installation Dyvi Delta on 26 July 1984 and drilled to TD\r\nat 4005 m in Late Triassic sediments of the Raude Formation. The well was\r\ndrilled with gel/seawater down to 615 m, with gypsum/CMC/lignosulphonate from\r\n615 m 3196 m, and with gel/lignosulphonate from 3196 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo sandstones were encountered in the\r\nEarly Cretaceous. Hydrocarbon bearing Brent sandstone was encountered at 3287\r\nm, with the hydrocarbon/water contact established at 3333 m+/-3 m. No\r\nhydrocarbons were identified in the Cook sandstones. The logs indicated\r\nhydrocarbons in the Statfjord Group, but drill stem test gave no flow from\r\nthese sandstones. No shows were described above the Tarbert reservoir. Below\r\nthe OWC, shows on sandstone were described down to 3359 m.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eSix cores were cut; four from 3289 m to\r\n3383 in the Brent Group and two from 3970 m to 3985.5 in the Raude Formation.\r\nCore recoveries were from 90 % to 100 %. RFT fluid samples were taken in the\r\nBrent Group oil zone at 3298.5 m, 3317.3 m, and 3325.0 m.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was permanently abandoned on 22\r\nOctober 1984 as a gas appraisal well.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eTesting\u003c/span\u003e\u003c/b\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyTex","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"217","properties":{"OBJECTID":217,"wlbNpdidWellbore":222,"wlbName":"34/10-7","wlbHistory":"\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 34/10-7 was drilled on the eastern\r\nsegment of the Gullfaks Field. The primary objective was to test sandstones of\r\nMiddle Jurassic age. Secondary objective was sandstones of Early Jurassic age:\r\nthe Cook and the Statfjord Formations.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 34/10 7 was spudded with\r\nthe semi-submersible installation Ross Rig on 7 January 1980 and drilled to TD\r\nat 2550 m in the Late Triassic Lunde Formation. Two major problems were\r\nencountered during drilling. The first one concerned water sensitive clays\r\nwhich caused difficulties when underreaming the hole for both the 16"\r\nliner and the 13 3/8" casing. The second problem was the leak off test\r\nbelow the 9 5/8" casing shoe. While circulating prior the second leak off test\r\nthe formation broke down. Four cement squeezes were required before a proper\r\nformation test was obtained. The well was drilled with spud mud down to 845 m\r\nand with gel/lignosulphonate mud from 845 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWeak to good oil shows were recorded from\r\n1320 m in the lower Hordaland Group and downwards, mostly in limestone. Strong\r\nshows with live oil in the mud were recorded between 1380 and 1415 m. Oil shows\r\nof variable strength continued all the way down through the Hordaland, Rogaland\r\nand Shetland Groups. The Shetland Group was found resting directly on the Early\r\nJurassic Cook Formation sandstone at 1810 m. Oil was found in sandstones of the\r\nCook and Statfjord Formations. No oil/water contact was observed in the Cook\r\nFormation. In the Statfjord Formation an oil water contact was found at 2066 m.\r\n\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eA total 53.2 m core (67% recovery) was\r\nrecovered in 5 cores in the interval from 1813 m to 1892 m. A sixth core was\r\ntaken with 100% recove","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"218","properties":{"OBJECTID":218,"wlbNpdidWellbore":223,"wlbName":"1/3-5","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 1/3-5 was drilled on a NW-SE\r\noriented fault block tilted towards the NW. The structure is located in the\r\nnorthern Permian basin, on the east side of Central Graben, extending into\r\nblocks 116, 211, and 2/4. The purpose of the well was to evaluate the\r\nhydrocarbon potential of the Rotliegendes Group sandstones.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 1/3-5 was spudded with the\r\n3-leg jack up installation Neddrill Trigon on 1 October 1984 and drilled to TD\r\nat 4850 m in the Permian Rotliegendes Group. After setting the 30"\r\nconductor a 14 3/4" pilot hole was drilled to 1195 m, before opening the\r\nhole to 26". Drilling to 2470 m the mud weight was raised from 1.33 g/cm3\r\nto 1.70 g/cm3 due to high formation pressure. This resulted in tight hole\r\nduring wiper trips, and high weight strain on the drill string, and also caused\r\nthe 13 3/8" casing to be set somewhat higher than prognosed. Through the\r\nchalk sequence the hole seemed to be tight, and while tripping at 3523 m, the\r\ndrill string got stuck with the bit at 3515 m. It was assumed that the tight\r\ninterval was caused by one of the stabilizers between 3247 and 3267 m. The\r\nstring was freed by pumping acid. A high pressure sand sequence in the interval\r\n4363-4395 m, with pore pressure close to the last leak-off Test, resulted in\r\nthe 7" liner being set 520 m higher than prognosed. The well was drilled\r\nwith spud mud down to 1195 m, with KCl/polymer mud from 1195 m to 3000 m, from\r\n3000 m the mud was lightly treated with lignosulphonate. Fifty bbl of pipelax\r\nwith a mud/diesel ratio of 1:1 was added to the mud to free the stuck pipe at\r\n3515 m. From 4122 m to TD the well was drilled with a polymer/sulphonated resin\r\nmud.\u003c/p\u003e\r\n\r\n\u003cp\u003eTraces of yellow direct fluorescence,\r\nmainly on fractures, with a moderate milky-white cut fluorescence were observed\r\nat the top of the Tor Formation and at several levels deeper down in the\r\nformation. Also near the base of the Hod Formation, a very weak ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"219","properties":{"OBJECTID":219,"wlbNpdidWellbore":224,"wlbName":"2/6-2","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 2/6-2 is located on the Piggvar\r\nTerrace just east of the Mandal High in the southern Norwegian North Sea. The\r\nmain objective of the 2/6-2 well was to test a possible hydrocarbon\r\naccumulation of a lens-shaped seismic anomaly in the Lower Cretaceous. The\r\nanomaly showed both up dip truncation and structural closure, it was believed\r\nto represent a deep sea fan type sand deposit. A secondary objective was to\r\nexplore the upper part of the Jurassic series below the Kimmeridgian unconformity.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well is Reference well for the Tuxen\r\nFormation.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 2/6-2 was spudded with the\r\nsemi-submersible installation Dyvi Alpha on 3 January 1980 and drilled to TD at\r\n4760 m in Permian Zechstein salt. The hole was side-tracked from 4175 m due to\r\nloss of MFT tool in the hole at 4276 m.\u003c/p\u003e\r\n\r\n\u003cp\u003eIn the Early Cretaceous only tight,\r\nmainly water bearing limestones were found. The Jurassic consisted of the\r\nMandal, Farsund, Haugesund, and the Bryne Formations, with the latter resting directly\r\non the salt at 4723 m. In the Late Jurassic a hydrocarbon bearing but tight limestone\r\nbody was unexpectedly found. The Middle Jurassic Bryne sandstones were found\r\ngas bearing. Shows were reported as follows: Down to the top of the Jurassic at\r\n4118 m only minor amounts of gas were recorded and the first occurrence of C2 was\r\nseen at 4100 m. Fluorescence of a yellow golden colour and greenish white cut\r\nwas seen on Early Cretaceous limestones from 3870 to 3877 m, this led to the\r\ncutting of Core 1 at 3877 to 3886 m. On the core no direct fluorescence was\r\nseen, only a weak, cloudy yellow/greenish cut which terminated at 3881 m. Direct\r\nfluorescence and cut was seen on Late Jurassic limestones between 4179 and 4230\r\nm, further, on Cores 2 and 3 taken from 4220 to 4235.5 m there was seen good\r\nyellow to bluish direct fluorescence. Some bubbling of gas was also seen and\r\nseepage of oil from shaly joints. Some cut was seen on siltstone at ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"220","properties":{"OBJECTID":220,"wlbNpdidWellbore":225,"wlbName":"2/7-15","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 2/7-15 was drilled on the Eldfisk\r\nEast structure in the Feda Graben of the southern North Sea. The well was an\r\nappraisal of the productive Danian - Late Cretaceous chalks found in 2/7-8. The\r\nwell also had an explorative objective, namely to prove the existence of\r\nproductive Jurassic sandstones on the East Eldfisk structure. Projected total\r\ndepth was 14500 ft (4420 m).\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well is Reference well for the Ran\r\nSandstone Units.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 2/7-15 was spudded with the\r\nsemi-submersible installation Haakon Magnus (now Borgsten Dolphin) on 29\r\nJanuary 1980 and drilled to TD at 4423 m in the Late Jurassic Haugesund\r\nFormation. A 2.3 Sm3 influx was taken while drilling at 3667.7 m (3672.8 m logger's\r\ndepth) in the Farsund Formation. The well was shut in. After shut-in the\r\ncirculation was lost, probably because the formation broke down. The\r\ncirculation was resumed by appropriate mud adjustments, and the return mud then\r\ncontained 3% oil and was slightly gas-cut. The well was drilled with bentonite,\r\nFlosal and lime down to 503 m, with Drispac mud from 503 m to 1387 m, and with\r\nDrispac/lignosulphonate mud from 1387 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe Danian - Late Cretaceous section\r\ntested small quantities of hydrocarbons. Shows were encountered, often in\r\nfractures, on cored siltstone and claystone in the Early Cretaceous Ran\r\nSandstone Units and Åsgard Formation, but testing proved the section to be\r\ngenerally tight. The logs indicated a 2 m HC-bearing sandstone stringer at 3672.8\r\nm (where the influx was taken while drilling), but no shows were reported from\r\nthis depth. Isolated shows, in the form of dull yellow fluorescence, were\r\nreported also on cored claystone in the Farsund Formation at 403","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"221","properties":{"OBJECTID":221,"wlbNpdidWellbore":226,"wlbName":"8/10-2","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 8/10-2 was drilled on the\r\nSørvestlandet High about 20 km east of the Ula Field. The primary objective of\r\nthe well was Jurassic sandstones expected to be 122 m thick. Secondary\r\nobjective was Paleocene sandstones.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 8/10-2 was spudded with the\r\nsemi-submersible installation Nortrym on 5 February 1980 and drilled to TD at\r\n2997 m in the Late Permian Zechstein Group.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe first samples to the surface were\r\nfrom Miocene - Oligocene. They were badly contaminated with cement from the\r\ncasing shoe at 461 m. First clean formation samples were collected at 503 m and\r\nthey consisted of a soft grey brown clay with minor amounts of fine to medium\r\ngrained sand and occasional fossil frogs. This gave way at 570 m to a totally\r\nargillaceous section, and soft grey-brown, slightly calcareous, claystone was\r\nfound. This became the dominant lithology down to the 13 3/8" casing point\r\nat 1198 m. After casing point, cement contamination of samples occurred for\r\nabout 10 m. The claystone gave way to a grey-green-brown, soft, sticky clay,\r\nwhich had occasional traces of carbonaceous material. Top Hordaland Group is\r\nset at 1265 m. At 1471 m a thin hard white limestone occurred with an\r\nassociated drop in drilling rate from 61 m to 46 m per hour. Background gas\r\nalso decreased during this interval. After 1494 m the dominant lithology became\r\nsoft grey-brown clay, some sections of which were slightly calcareous.\r\nOccasional fossil fragments and pyrite nodules were also found in this section.\r\nThere was a slow increase in the claystone content and by 1801 m a light grey\r\nclaystone had become the dominant lithology. This claystone was moderately\r\nhard, slightly calcareous and micro micaceous; traces of dolomite and shelly\r\nfragments were also found. By 1951 m the soft clays had disappeared completely\r\nand were replaced by light grey and dark brown claystones, both soft to firm,\r\nthe light grey claystone being non-calcareous and the","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"222","properties":{"OBJECTID":222,"wlbNpdidWellbore":227,"wlbName":"31/2-2","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 31/2-2 was drilled some 4 km east of\r\nthe discovery well 31/2-1 on seismic line 79-416 at SP 200. The concession\r\nrequirement for the wells were complete penetration of the prospective Jurassic\r\nsequence and terminate in Triassic or older. The particular objectives of well\r\n31/2-2 were: to evaluate lateral variation of reservoir parameters eastwards on\r\nthe flank of the structure: to test the zone of oil shows seen in 31/2-1 in\r\nbetter reservoir conditions, to test the gas accumulation in a down-dip\r\nlocation: to evaluate the nature of the seismic flatspot, and to provide\r\ngeological calibration of seismic reflectors above the reservoir for improved\r\nregional evaluation.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell was spudded with the\r\nsemi-submersible installation West Venture on 27 February 1980 and drilled to\r\nTD at 1857 m in the Middle Jurassic Krossfjord Formation. The 36" hole was\r\ndrilled without incident to 433 m using seawater with viscous pills spotted on\r\nconnections. From 422 m to 433 m hard drilling was experienced. This was\r\ninterpreted as a boulder bed similar to that found at a comparable depth in the\r\nprevious 31/2-1 well. Problems were encountered with the stability of the\r\ntemporary guide base, and the well had to be abandoned. The rig was moved NE 25\r\nm and re-spudded on 29 February. The well was drilled with seawater and hi-vis\r\npills down to 800 m, and with gypsum/lignosulphonate mud from 800 m to TD. \u003c/p\u003e\r\n\r\n\u003cp\u003eTop reservoir (Sognefjord Formation) came\r\nin at 1544 m and was gas bearing down to a gas/oil contact at 1579 m, and\r\noil-bearing from 1579 m down to an oil/water contact at 1591 m. Both contacts\r\nwere clearly defined on logs, the gas/oil contact was confirmed by RFT pressure\r\ngradients, and moveable oil was confirmed by RFT sampling at 1587.5 m and 1590\r\nm. Gas samples were obtained from 1548 m and 1571 m. Weak oil shows began at\r\n1561 m in the gas zone, strong shows with stained and bleeding cores and a\r\nparaffinic smell were obs","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"223","properties":{"OBJECTID":223,"wlbNpdidWellbore":228,"wlbName":"34/4-2","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 34/4-2 is located in the northern North Sea, approximately 5 km west of the Snorre Field. The purpose of the well was to test\r\nthe stratigraphic sequence below the Base Cretaceous Unconformity. The primary\r\ntarget was the Statfjord Formation, which was known from the license 037 area\r\nto contain porous sandstones of appreciable thicknesses.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe secondary target was possible Brent\r\nGroup / Late Jurassic sands immediately below the Base Cretaceous unconformity.\r\nThirdly, well 34/4-2 was a stratigraphic test of the Triassic deposits between\r\nthe Statfjord Formation and the Middle to Late Triassic sequence penetrated in\r\nwell 34/4-1.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 34/4-2 was spudded with the\r\nsemi-submersible installation Byford Dolphin on 6 March 1980 and drilled to TD at 3599 m in the Late Triassic Lunde Formation. No significant incidents\r\noccurred during operations, but the well developed as much as 20 deg deviation\r\ntowards TD, giving a TVD RKB of 3571 m, 28 m less than measured depth. The well\r\nwas drilled with spud mud down to 816 m, with gypsum/lignosulphonate mud from\r\n816 m to 1975 m, and with lignosulphonate mud from 1975 m to TD. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe well penetrated Tertiary, Cretaceous,\r\nJurassic and Triassic strata as required in the work programme for License 057.\r\nMore than 900 m of Triassic deposits were penetrated in order to obtain\r\nstratigraphic information. The Statfjord Formation was eroded and the reservoir\r\ncharacteristics here were on large negative. The exception was the upper seven\r\nmeter thick Eiriksson Member with a net/gross-value of 1.00 and an average\r\nporosity of 24.3%. The underlying Raude Member had a high clay content, which\r\nreduced prospectiveness to a N/G value of 0.18 and porosities only rarely\r\nexceeding 20%. The Jurassic sequence proved to be different from the expected\r\nwith Dunlin Group claystones directly underlying Barremian limestones. Hence,\r\nno Brent/Late Jurassic sands were present. \u003c/p\u003e\r\n\r\n\u003cp\u003eNo s","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"224","properties":{"OBJECTID":224,"wlbNpdidWellbore":229,"wlbName":"16/4-1","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 16/4-1 is located on the Utsira\r\nHigh. The primary objective of the well was to test the Paleocene Heimdal\r\nFormation. Secondary objectives were Jurassic and Triassic sandstones,\r\nZechstein carbonates and Rotliegendes conglomerates. The well was planned to\r\nreach TD at 2850 m + 100 m after having identified a seismic reflector at this\r\ndepth, interpreted to represent Top Metamorphic Basement.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 16/4-1 was spudded with the\r\nsemi-submersible installation Treasure Seeker on 8 September 1984 and drilled\r\nto TD at 2909 m in crystalline/metamorphic basement of Early Paleozoic age.\r\nUnder the 30" casing shoe a 17 1/2" pilot hole was drilled. At 494 m\r\nin Pleistocene sand and shale, the well started to flow up the annulus from a\r\nsmall gas pocket. The well died out by itself but there were problems with lost\r\ncirculation, so a cement plug was set from 494 - 415 m. The cement was drilled\r\nout to 480 m and the hole was underreamed to 26" before landing of the\r\n20" casing. No other major problems occurred during drilling of this well.\r\nThe well was drilled with seawater and bentonite down to 494 m, with\r\nKCl/polymer mud from 494 m to 2052 m, and with NaCl/polymer mud from 2052 m to\r\nTD. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe well 16/4-1 encountered water-bearing\r\nsandstones in the Paleocene Heimdal Formation as well as in the Triassic. The\r\nlatter is a 36 m thick sand in between the Smith Bank Formation and the\r\nZechstein Group. The Heimdal Formation Sandstones occur as interbedded\r\nsand/claystone in the upper part (2100 m to 2142 m) and as a massive sandstone,\r\nwhich is homogenous and very clean in the lower part (2142 m 2277 m). The\r\nTriassic sandstones (2394 m to 2430 m) were very fine-to-fine grained with a\r\nconsiderable amount of silt and mica. Log evaluations over these sands gave the\r\nfollowing results: The interval 2100 m to 2142 m gave a net/gross ratio of\r\n0.095, with an average porosity of 23,06% and a shale volume of 43,58%","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"225","properties":{"OBJECTID":225,"wlbNpdidWellbore":230,"wlbName":"34/10-8","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 34/10-8 was drilled on the southern\r\npart of the Gullfaks Field. The primary objective was to test sandstones of\r\nMiddle Jurassic age. Secondary objectives were sandstones in the Early\r\nJurassic.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 34/10-8 was spudded with\r\nthe semi-submersible installation Deepsea Saga on 8 March and drilled to TD at 2214\r\nm in the Early Jurassic Cook Formation. Some problems with lost circulation was\r\nencountered when circulating prior to cementing the 13 3/8" casing. Also\r\nthe drill string became stuck during plug back operations at 2037 m and 9 days\r\nwere lost when fishing for it. The well was drilled with Gel/spud mud down to 875\r\nm and with gel/lignosulphonate from 875 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe Middle Jurassic Brent Group sandstones\r\ncame in with Tarbert Formation on top at 1821 m and the Ness Formation at 1853\r\nm. The Tarbert and Ness formations were hydrocarbon-bearing with a 151 m gross\r\npay zone from1821 to 1972 m. The Early Jurassic sandstones of the Cook\r\nFormation were water saturated. Above the reservoir good oil shows were\r\nrecorded on limestone from 1712 to 1745 m and on limestone/mudstone/siltstone\r\nfrom 1665 to 1705 m. Otherwise traces of oil shows were recorded above the\r\nreservoir up to a depth of 1220 m. No shows were recorded below the oil bearing\r\nreservoir.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eA total of 13 cores were taken from 1823 to\r\n1976 m, with a total recovery of 140 m. The RFT tool was run in the Brent sand\r\nand good data was obtained from 1826 to 2006 m. Fifteen out of seventeen tests\r\nwere successful. In the Ness zone a fluid sample was taken at 1950 m.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was permanently abandoned on 25\r\nMay 1980 as an oil appraisal well.\u003c/s","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"226","properties":{"OBJECTID":226,"wlbNpdidWellbore":231,"wlbName":"15/9-6","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 15/9-6 was drilled in the Sleipner\r\nVest area in the Viking Graben of the North Sea. The objective of the well was\r\nto test possible hydrocarbons in Middle Jurassic sandstones on the northern\r\nflank of the 15/9-Beta structure, and to get more information about the sand\r\ndistribution in this area.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 15/9-6 was spudded with\r\nthe semi-submersible installation Nordskald on 7 May 1980 and drilled to TD at\r\n3946 m in the Triassic Skagerrak Formation. No significant problem was\r\nencountered in the operations. The well was drilled with seawater and\r\npre-hydrated gel down to 465 m, with sweater/gel and SSP lubricant (a vegetable\r\noil) from 465 m to 1140 m, and with gel lignosulphonate/SSP lubricant from 140\r\nm to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eTop of the target reservoir sandstones (Callovian\r\nage Hugin Formation) was found at 3762 m. This was deeper than expected and below\r\nthe field gas-water contact. The sandstones were also thinner than expected. Isolated\r\nspots of shows on sandstones were described on cuttings and cores from the Hugin\r\nand Sleipner formations and the Upper part of the Skagerrak Formation. One\r\ncuttings sample from 3346 m in the Blodøks Formation was described with good\r\nshow on sandstone.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eTwo cores were cut. Core 1 was cut from\r\n3768.5 m to 3781.4 m in the Hugin Formation (75% recovery) and core 2 was cut\r\nfrom 3810 m to 3814.5 m in the Sleipner Formation (37% recovery). An RFT fluid\r\nsample was taken at 3774 m in the Hugin Formation. Laboratory analysis\r\nindicated the content to be a mixture of formation water, mud, and fresh water\r\nfrom the water cushion in the sampler. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was permanently abandoned on 7\r\nSept","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"227","properties":{"OBJECTID":227,"wlbNpdidWellbore":232,"wlbName":"2/7-16","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 2/7-16 was drilled on a\r\nstructure on a broad terrace to the south of Edda field and with a geological\r\nenvironment similar to Edda. The primary objective was to test the potential\r\nfor hydrocarbon production from Danian and Late Cretaceous Limestones on a low\r\nrelief structural closure. Secondary objective was a possible stratigraphic\r\ntrap potential in Early Cretaceous sandstones.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 2/7-16 was spudded with the\r\nsemi-submersible installation Nortrym on 20 March 1980 and drilled to TD at\r\n4818 m in the Early Cretaceous Ågard Formation. The well was drilled with\r\nSeawater/Native Solids mud down to the 13 3/8" casing point at 1523 m,\r\nwith Seawater/Lignosulphonate from 1523 m to the 9 5/8" casing point at\r\n3794 m, and with Calcium chloride/Sodium chloride XC polymer mud from 3794 m to\r\nTD.\u003c/p\u003e\r\n\r\n\u003cp\u003eHydrocarbon shows were encountered in the\r\nDanian and Upper Cretaceous limestone. The porosity was poorly developed and\r\ntesting verified the zones to be non-productive. Early Cretaceous had shows in\r\nlimestones, claystones, shales, and marls, but no sandstones were found.\u003c/p\u003e\r\n\r\n\u003cp\u003eThirteen conventional cores were cut\r\ncontinuously from 3182 m to 3402 m in the Ekofisk and Tor Formations\r\nFormations. Twenty-five RFT measurements were attempted in the gross interval\r\n3823.8 - 4783.6 m. A fluid sample was obtained at 4587.9 m. It contained 50 ml\r\nformation water and 39 cubic feet (1.1 Sm3) gas.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 12\r\nJuly 1980 as a dry well with shows.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eTwo drill stem tests were conducted. DST\r\n1 at 3279.7 to 3288.8 m in the Tor Formation produced 660 barrels (105 m3) of\r\nwater /day, with traces of oil and gas. DST 2 from the intervals 3193.1 -\r\n3199.8 and 3201.4 - 3215.4 m in the Ekofisk Formation produced 28.8 barrels\r\n(4.6 m3) water /day with no oil or gas before acid treatment. Well died\r\ncompletely after acid, with only a very weak flow of acid gas.","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"228","properties":{"OBJECTID":228,"wlbNpdidWellbore":233,"wlbName":"34/7-2","wlbHistory":"\r\n\r\n\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 34/7-2 was drilled just north of the\r\nTordis Øst discovery in the northern North Sea. The main objectives were to\r\ntest for hydrocarbons in the Jurassic Statfjord Formation and in the Triassic\r\nLunde Formation. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 34/7-2 was spudded with the\r\nsemi-submersible installation Treasure Saga on 2 September 1984 and drilled to\r\nTD at 2475 m in the Late Triassic Lunde Formation. A total of 83 hours rig time\r\nwas NPT due to repairs resulting from a failed RIH with the 26" bit after\r\nunderreaming to 816 m, and a leak in the acoustic system discovered after\r\nsetting the 9 5/8" casing at 2031 m. The well was drilled with seawater\r\nand hi-vis pills down to 848 m, with KCl/polymer mud from 848 m to 2042 m, and\r\nwith lignosulfonate mud from 2042 m to TD. No shallow gas was encountered.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eExcept for the sandy Utsira Formation and\r\ntwo sandstone units in the Hordaland Group (in the order of 40 - 50 m each) the\r\nwell proved mainly claystones down to the Statfjord Formation at 2152 m. At BCU\r\n(2085 m) there was a major hiatus from Pliensbachian to Campanian. The Lunde\r\nFormation was encountered at 2271 m. The gross thickness of the Statfjord in\r\nthis well is 119 m with 43.5 m of net sand. The well drilled some 204 m into\r\nthe Lunde Formation, which in the upper part proved a siltstone sequence with\r\nminor sandstone and claystone, while the lowermost 117 m proved a sequence of\r\nsandstones alternating with claystones. Of this sequence some 41.3 m could be\r\nconsidered as net. No live hydrocarbons were encountered by the well. Residual\r\noil was found in base Amundsen - top Statfjord Formations, however, cores showed\r\nlow porosity and essentially no net sand. Ex","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"229","properties":{"OBJECTID":229,"wlbNpdidWellbore":234,"wlbName":"16/8-2","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eExploration well 16/8-2 is located in the\r\nLing Depression south of the Utsira High and North of the Danish Norwegian\r\nBasin. The primary target was Late Jurassic sandstones; secondary target was\r\nthe Danian/Late Cretaceous limestones and Rotliegendes/Devonian sandstones. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 16/8-2 was spudded from the\r\nsemi-submersible installation Sedco H on 3 April 1980 and drilled to TD at 3585\r\nm in Late Permian Zechstein evaporites. The well was drilled with bentonite and\r\nseawater down to 542 m, with a Spersene lignosulphonate/gypsum/CMC mud from 542\r\nm to 2275 m, and with a salt saturated Drispac polymer/XC polymer/Polysal\r\nstarch mud from 2275 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eDown to the setting of the 13 3/8"\r\ncasing, the well progressed as programmed. However, the absence of the Triassic\r\nand the appearance of the Zechstein evaporites much shallower than expected\r\ncaused the 9 5/8" casing to be set 474 metres higher than programmed. The\r\ndrilling of the 8 1/2" hole commenced with a 1.45 SG salt saturated mud as\r\nprogrammed. Two runs with a turbine/Stratapac bit were made. However, on\r\npulling out of the hole from 3519 m, tight hole was encountered and while\r\nattempting to work through this section, the drill string parted leaving 32.81\r\nm of BHA at a depth of 3462 m. On running in with an overshot, the well was\r\nobserved to be flowing. It was shut in but pressure continued to increase even\r\nafter the appropriate mud weight increases had been effected. The mud weight\r\nwas eventually raised to 2.03 SG creating a fine balance between sufficient\r\nfluid density and exceeding fracture pressure. The influx (thought to be from a\r\nCarnallite zone at approximately 3513 m) had an adverse effect on the mud\r\nproperties causing the barite to settle out and reducing the pH to an acidic\r\nlevel. The magnesium and calcium sensitive Drispac polymer was replaced with\r\nthe more tolerant 'XC Polymor1 to maintain the barite in suspension, and an\r\ninhibitor was ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"230","properties":{"OBJECTID":230,"wlbNpdidWellbore":235,"wlbName":"31/4-7","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 31/4-7 was drilled on the southernmost\r\npart of the Brage Horst, close to the junction between the Brage/Oseberg fault\r\nand the Troll Fault. The primary objective was to test the hydrocarbon\r\npotential and the internal stratigraphy on the Brage Horst compartment on the\r\nwestern flank of the Brage Field. Neighbouring well 31/4-2 to the north on the\r\nBrage Horst found live oil in two thin sandstones in the Brent Group, while\r\nwells 31/4-3, 4, and 5 on the main Brage structure on the Bjørgvin Arch had\r\nproved oil in the "Intra-Heather Sandstone Unit II" (Fensfjord\r\nFormation). The well was planned to be drilled 50 m into the Statfjord Group at\r\n2765 +/- 50 m.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 31/4-7 was spudded with the\r\nsemi-submersible installation Vildkat Explorer on 26 July 1984 and drilled to\r\nTD at 2505 m in Late Triassic sediments of the Statfjord Group. No significant\r\nproblem was encountered in the operations. The well was drilled with gel/spud\r\nmud down to 1000 m, with KCl/polymer mud from 1000 m to 1816 m, and with a\r\nNaCl/polymer mud from 1816 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well encountered hydrocarbon bearing\r\nsandstones and siltstones in the Fensfjord Formation and in the Statfjord Group\r\nsandstones. The Fensfjord Formation was poorly developed with sandstones\r\ngrading to siltstones followed by siltstones. It was found gas bearing over the\r\ninterval 2026 - 2056 m with a calculated net pay of 8 m, an average porosity of\r\n20.5% and an average water saturation of 45%. The Statfjord Group came in at 2384\r\nm and was found oil bearing down to the OWC at 2406 m. It consisted of fine to\r\ncoarse sandstones. The net pay was calculated to be 12.5 m with a calculated\r\naverage porosity of 22.2% and an average water saturation of 42.3%. \u003c/span\u003e\u003c/p\u003e\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"231","properties":{"OBJECTID":231,"wlbNpdidWellbore":236,"wlbName":"31/2-3","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 31/2-3 was drilled in the Troll West\r\narea, approximately 8 km NNE of the Troll Discovery well 31/2-1. The well was\r\ndrilled to appraise the Troll Discovery. It should evaluate reservoir\r\nparameters along the axis of maximum gross hydrocarbon column; prove maximum\r\nhydrocarbon reserves in the major northern fault block; confirm the\r\nsignificance of the seismic flatspot as a direct hydrocarbon indicator; further\r\nassess the significance of the oil shows found in 31/2-1; and evaluate the\r\ninfluence of earlier Kimmerian fault movements on reservoir characteristics.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eAppraisal well 31/2-3 was spudded with\r\nthe semi-submersible installation Borgny Dolphin on 28 March and drilled to TD\r\nat 2601 m in Late Triassic sediments in the Statfjord Formation. Drilling took\r\n115 days. The reason for the long drilling period was safety inspection of the\r\nrig as a result of the "Alexander Kielland" accident and a strike\r\namongst the Norwegian rig crew. The well was drilled with bentonite and\r\nseawater down to 816 m and with a gypsum/lignosulphonate mud from 816 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eNo potential reservoir zones were\r\nencountered above top Jurassic. The well confirmed that the Late Jurassic\r\nsandstone reservoir encountered in wells 31/2-1 and 2 was well developed also\r\nin this more northerly part of the structure. A gross gas column of 189 m was\r\npenetrated with top at 1384 m. The uppermost 120 m was in a good clean sand\r\n(Sognefjord Formation) while the lower part of the gas column was in a\r\nmicaceous and poor reservoir sand (Heather and Fensfjord Formations). Below the\r\ngas a 12 m thick oil zone was encountered, the same thickness and at the same\r\nlevel as in well 31/2-2. In this well however, the oil was in a very micaceous\r\nand poorly developed reservoir. The reservoir was uncomformably overlain by\r\nPalaeocene claystones, which thus act as an effective seal for the reservoir.\r\nBelow the OWC at 1585 no moveable hydrocarbons were seen in th","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"232","properties":{"OBJECTID":232,"wlbNpdidWellbore":237,"wlbName":"1/5-1","wlbHistory":"\r\n\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe Flyndre (1/5-1) well was drilled on a\r\nstructural high situated in the Feda Graben of the North Sea close to the UK\r\nborder.\u00A0 At the commencement of the well the principle objective horizons were\r\nthe Paleocene and Jurassic sand sections which had produced oil in the UK 30/13-2\r\nwell and the NO 2/7-3 wells respectively.\u00A0 It was estimated that at Paleocene\r\ndepth the structure was an irregular dome about 4 miles in diameter, with 12 square\r\nmiles of closure and 290 ft (88.4 m) of vertical relief while at Jurassic depth\r\nthe structure was a NW-SE trending anticline 4.5 miles by 3.5 miles with 12\r\nsquare miles of closure at 190 ft (57.9 m) of vertical relief. Planned TD was\r\n15000 ft (4572 m), Triassic sands, or the Zechstein Group, whichever came\r\nfirst.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 1/5-1 was spudded with the\r\nsemi-submersible installation Ocean Viking on 12 October 1973. The well was\r\ndrilled to 491 m in the Nordland Formation. When running 20" casing the\r\ncasing got stuck. After an unsuccessful fishing operation the well was permanently\r\nabandoned on 19 October 1973 as a junk well. No cores were cut and no wire line\r\nfluid samples were taken.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eReplacement well 1/5-2 was spudded 15 m\r\naway in a 320 deg true direction.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eTesting\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo drill stem test was performed.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"233","properties":{"OBJECTID":233,"wlbNpdidWellbore":238,"wlbName":"1/5-2","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe Flyndre well (1/5-2) was drilled on a\r\nstructural high situated in the Feda Graben of the North Sea close to the UK\r\nborder. The principle objective horizons were the Paleocene and Jurassic sand\r\nsections which had produced oil in the UK 30/13-2 well and the NO 2/7-3 wells. It\r\nwas estimated that at Paleocene depth the structure was an irregular dome about\r\n4 miles in diameter, with 12 square miles of closure and 290 ft (88.4 m) of\r\nvertical relief while at Jurassic depth the structure was a NW-SE trending\r\nanticline 4.5 miles by 3.5 miles with 12 square miles of closure at 190 ft (57.9\r\nm) of vertical relief. Planned TD was 15000 ft (4572 m), Triassic sands, or the\r\nZechstein Group, whichever came first. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003ca name=\"OLE_LINK2\"\u003e\u003c/a\u003e\u003ca name=\"OLE_LINK1\"\u003e\u003cspan\r\nlang=EN-GB\u003eWell 1/5-2 \u003c/span\u003e\u003c/a\u003e\u003cspan lang=EN-GB\u003ewas spudded on 19 October\r\n1973, 15 m away from the original Flyndre well 1/5-1, which was junked at 491 m\r\nfor technical reasons. Well 1/5-2 was drilled with the semi-submersible\r\ninstallation Ocean Viking. Total depth was set at 4287 m in Late Permian Zechstein\r\nsalt. The well was drilled with seawater and hi-vis pills down to 494 m. The\r\nrest of the well was drilled with lignosulphonate mud.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well had shows throughout the\r\nPaleocene and Late Cretaceous sections and four drill-stem tests were carried\r\nout.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe top sand in Paleocene at 2832 m (Forties\r\nFormation sand) produced oil upon testing. Mud log shows were present in the\r\nDanian, but testing proved the section to be tight and unproductive. A thick Late\r\nCretaceous section was encountered with oil shows at the top of the Maastrichtian\r\n(Tor Formation) and in the Campanian (Lower Tor and Hod Formation) sections. Drill-stem\r\nt","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"234","properties":{"OBJECTID":234,"wlbNpdidWellbore":239,"wlbName":"1/6-1","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 1/6-1 is located ca 15 km\r\nnorthwest of the Ekofisk Field in the southern Norwegian North Sea. It was\r\ndrilled in a crestal position on a large chalk structure shared between Norske\r\nShell's block l/6 and Phillips' block 2/4, the Ekofisk block. Phillips\r\nparticipated in drilling this well on a 50/50 basis. The primary objective was\r\nto investigate Danian and Maastrichtian chalk prospects. Secondary objective\r\nwas to evaluate possible sand developments in the Paleocene and the Lower\r\nCretaceous or older units. Planned total depth was 4572 m (1500 ft).\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 1/6-1 was spudded with the jack-up\r\ninstallation Zapata Nordic on 10 July 1972 and drilled to TD at 4822 m in the\r\nLate Permian Zechstein Group. No major technical problems were encountered in\r\nthe operations and the drilling of this deep well was within the prognosed time\r\nschedule. The drill string stuck at 228 m. After working the string and\r\nspotting pipe-free/diesel the string came loose. Some highly porous limestone\r\nintervals (1 - 8 m thick) resulted in lost circulation problems. The pipe stuck\r\nat 3456 m, but was freed after spotting with pipe-free/diesel. The well was\r\ndrilled with seawater down to 448 m, with seawater/lignosulphonate and a shale\r\ninhibitor (shalock) from 448 m to 1586 m, and with\r\nseawater/lignosulphonate/ligcon (caustisized lignite) from 1586 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eReservoir development was encountered\r\nonly in the Chalk Formations, with hydrocarbon-bearing intervals being\r\ndeveloped in both the Danian and Late Cretaceous. Four hydrocarbon-bearing\r\nintervals were encountered and tested within the Chalk, but only one zone in\r\nthe Maastrichtian (Tor Formation), yielded commercial flows of gas and\r\ncondensate. Reservoir developments in the Danian (Ekofisk Formation) and\r\nearlier Maastrichtian (Hod Formation) were found to be considerably less\r\nfavourable in l/6-l than in the adjacent Ekofisk and West Ekofisk field. The\r\nEarly Cretaceous (Valanginian) w","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"235","properties":{"OBJECTID":235,"wlbNpdidWellbore":240,"wlbName":"1/6-2","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 1/6-2 was drilled between the\r\nAlbuskjell and Flyndre Fields in the Feda Graben of the North Sea. The primary\r\nobjective was to evaluate the Danian and Maastrichtian Chalk prospects (Ekofisk\r\nand Tor Formations) of a prominent diapiric domal structure. The well was\r\nplaced on the flank of the structure.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 1/6-2 was spudded with the jack-up\r\ninstallation Zapata Nordic on 28 November 1972 and drilled to TD at 3383 m in\r\nthe Late Cretaceous Hod Formation. Some downtime recorded in the top hole was\r\ndue to a defect 20" casing shoe and bad weather, otherwise operations went\r\nforth without significant problems. The maximum deviation down to 3226.6 m was\r\n3.5 deg. The well was drilled with Sea water and viscous mud down to 460 m,\r\nwith Shaletrol mud from 460 m to 2445 m, and with Unical mud from 2445 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eIn the Tertiary shale sequence potential\r\nreservoirs were limited to a few very thin (0.5 m or less) limestone or\r\ndolomite streaks. Top of the Chalk was encountered at 3024 m. The reservoir\r\ndevelopment in the Chalk was rather poor throughout, with the exception of a\r\nzone of ca 12 m in the Danian Ekofisk Formation having a porosity of about 26%.\r\nThe Chalk formations were entirely water bearing as seen on the logs. However,\r\nweak hydrocarbon indications were observed in the Chalk (namely weak\r\nfluorescence and occasional slight oil staining), and relatively more abundant\r\nindications of oil staining and dead oil traces were recorded in the overlying Tertiary\r\nshales and interbedded carbonate layers.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eOne core was cut from 3226.6 m to 3241.5\r\nm in the Tor Formation. The core confirmed the generally dense nature of the\r\nChalk in this section. No wire line","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"236","properties":{"OBJECTID":236,"wlbNpdidWellbore":241,"wlbName":"1/6-3","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 1/6-3 is located on the Albuskjell\r\nField in the southern Norwegian North Sea. The primary objective was appraisal\r\nof reservoir development in the western part of the Albuskjell field. A Danian\r\n- Maastrichtian gas condensate field had previously been confirmed by two wells\r\n(A/S Norske Shell l/6-l and Phillips 2/4-9) drilled farther east along the WNW\r\n- ESE trending structure. Secondary objectives were to investigate Danian Chalk\r\nprospect and possible deeper prospects. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eAppraisal well 1/6-3 was spudded with the\r\njack-up installation Zapata Nordic on 12 April 1974. Three sidetracks had\r\nfinally to be drilled, of which the second and deepest reached 3343 m in the\r\nLate Cretaceous Tor Formation. The first sidetrack was kicked off at 314 m\r\nafter unsuccessful fishing (lost hole opener). The second sidetrack was kicked\r\noff at 3022 m when it was realised that a core point had been missed so that a\r\nDanian porous zone and 37 m of Maastrichtian had not been cored. Lost circulation\r\nand stuck pipe led to the third side track, which was kicked off at 2995 m.\r\nFurther lost circulation problems and the discovery that there was a break in\r\nthe casing at 3140 m finally led to abandonment of the well without\r\ninvestigating the deeper prospects. The well was drilled with seawater down to\r\n417 m, with shale-trol/lignosulphonate from 417 m to 1221 m, with\r\nshale-trol/lignosulphonate and lime from 1221 m to 2500 m, and with\r\nlignosulphonate and lime from 2500 m to TD. A diesel/pipe lax pill was spotted\r\nat 314 m.\u003c/p\u003e\r\n\r\n\u003cp\u003eAs prognosed, gas was encountered both in\r\nthe Danian and Late Maastrichtian Chalk. Hydrocarbons were present from Top\r\nEkofisk at 3110 m down to an OWC at 3289.7 m in the Tor Formation. The net\r\nthicknesses were respectively 91 and 45 m. The great thickness of the Danian\r\nreservoir was in contrast to the findings from wells l/6-l and 2/4-9, where\r\nonly a thin hydrocarbon-bearing zone was present in an otherwise tight Danian. ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"237","properties":{"OBJECTID":237,"wlbNpdidWellbore":242,"wlbName":"1/6-4","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 1/6-4 was drilled in the southernmost\r\npart of the Breiflabb Basin in the North Sea. The objective was to evaluate a\r\nlarge low relief base Tertiary - Late Cretaceous structure with potential\r\nreservoirs both in the Danian - Late Cretaceous Chalk and in the Paleocene\r\nSands. The primary target was the Chalk (Ekofisk and Tor formations).\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 1/6-4 was spudded with the\r\nsemi-submersible installation Chris Chenery on 29 December 1975 and drilled to\r\nTD at 3810 m in the Late Cretaceous Tor Formation. The drilling of 1/6-4 was\r\nbeset with rig mechanical problems, most notably failures in the mooring system\r\ninduced by adverse North Sea weather. All in all 34 days (ca 33%) of the total\r\nrig time on the well was counted as down time. The well was drilled with bentonite/seawater\r\nspud mud down to 437 m and with lime/Drispac/seawater mud from 437 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eTop Rogaland Group, Balder Formation,\r\ncame in at 3110 m. A Paleocene sandstone, Andrew Formation was penetrated from\r\n3197 to 3253 m. Top Shetland Group, Ekofisk Formation, came in at 3374 m. The Balder\r\nFormation (Tuff marker) had some residual hydrocarbons up to 30%. This was\r\nsubstantiated by gas readings and some shows of fluorescence in ditch cuttings.\r\nThe underlying Andrew Formation sandstones were found 100% water-bearing. Both the\r\nDanian and Maastrichtian were fully water bearing based on petrophysical\r\nanalyses. This was in agreement with the lack of oil/gas shows while drilling\r\nin this section.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo cores were cut and no wire line fluid\r\nsamples were taken.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was permanently abandoned on 9\r\nApril 1978 as a dry well with shows.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp cla","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"238","properties":{"OBJECTID":238,"wlbNpdidWellbore":243,"wlbName":"1/9-1","wlbHistory":"\r\n\r\n\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 1/9-1 was drilled on a salt diapir\r\nstructure located in the Feda Graben in the southern North Sea. The primary objective\r\nwas to test hydrocarbon accumulations in the Danian and Late Cretaceous chalk. A\r\nsecondary objective was to test the Jurassic and Triassic sandstones.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 1/9-1 was spudded with the\r\nsemi-submersible installation Ross Rig on 14 October 1976 and drilled to TD at\r\n3706 m in Cenomanian age limestone (Hidra Formation). The Jurassic was not\r\nreached. The anchor chain broke on three occasions. The third breakdown occurred\r\nduring the last DST. The decision was then made to suspend the well for later\r\nre-entry. The well was drilled with seawater and gel slugs down to 433 m, and\r\nwith seawater-lime-lignosulphonate from 433 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe Danian chalk (Ekofisk Formation) was\r\nreached at 3043.5 m just below a marl section. It consisted of two hydrocarbon\r\nbearing zones. Zone 1 from 3043.5 m to 3071.5 m and a tighter zone 2 from 3071.5\r\nm to 3103.5 m. Maastrichtian (Tor Formation) starts at about 3103.5 m and is\r\nalso hydrocarbon bearing with water saturations below 50% down to 3141.5 m. A\r\ntransition zone with gradually increasing water content is seen from 3134.0 m\r\ndown to 3182.5 m. Apart from in the oil bearing reservoirs weak oil shows on minor\r\nsandstones were recorded in the interval 2947 to 2958 m; weak to good oil shows\r\nwere seen on limestone in the interval 3300 m to 3500 m; and finally weak oil\r\nshows were seen occasionally from 3645 m to 3675 m.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe chalk section was cored in 11 cores from\r\n3048 m to 3235.5 m (Ekofisk and Tor formations) and one core (core no 12) from\r\n3327.2","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"239","properties":{"OBJECTID":239,"wlbNpdidWellbore":244,"wlbName":"1/9-2","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 1/9-2 was drilled on a salt diapir\r\nstructure located in the Feda Graben in the southern North Sea. It was drilled\r\nto confirm and further evaluate the proven hydrocarbons found on this seismic\r\nstructure by the 1/9-1 well.\u003cb\u003e \u003c/b\u003e\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 1/9-2 was spudded with the\r\nsemi-submersible installation Ross Rig on 1 June 1977 and drilled to TD at 3459\r\nm in the Late Cretaceous Hod Formation. No significant problems were\r\nencountered in the operations. The well was drilled with spud mud down to 439 m\r\nand water based with lime/Drispac/lignosulphonate mud systems from 438 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eGood oil show was observed in a thin\r\nsandstone stringer at 1632 m in the Hordaland Group. Oil in cuttings was\r\nrecorded also at 1710 m and 2858 m in claystones. The Ekofisk Formation was\r\nencountered at 3120 m with shows and tested small amounts of oil. The Tor Formation\r\ncame in at 3195 m with shows and tested small amounts of oil. Below 3213.5 m\r\nonly rare and weak fluorescence was observed on limestone.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe interval 3135-3215 in the Ekofisk and\r\nTor formations was cored with nearly 100% recovery. RFT pressure readings were attempted\r\nin the Tor and Ekofisk formations, but all were unsuccessful due to tight\r\nformation. No fluid samples were taken.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was permanently abandoned on 12\r\nAugust 1977. The poor results from DST are classified as shows.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eTesting\u003c/span\u003e\u003c/b\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eTwo drill stem tests were carried out. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eDST 1 tested the Maastrichtian Tor\r\nFormation (3197 - 32","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"240","properties":{"OBJECTID":240,"wlbNpdidWellbore":245,"wlbName":"1/9-3","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 1/9-3 is located in the Feda Graben,\r\nclose to the UK border southwest in the Norwegian North Sea. The primary\r\nobjective of the well was to evaluate the Jurassic sandstones. The secondary\r\nobjective was to appraise and test the hydrocarbon bearing zones of Danian and\r\nMaastrichtian age (Shetland Group) encountered in 1/9-1. The well was drilled\r\nin two phases, of which Phase I is well bore 1/9-3 and Phase II is well bore\r\n1/9-3 R. This procedure was a requirement from the Norwegian Petroleum\r\nDirectorate since Dyvi Gamma came directly from the yard and had therefore not\r\naccumulated the experience needed to drill the high pressure Jurassic well to a\r\nplanned TD of 5000 m. Phase II was to be drilled with the rig Dyvi Beta.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well was spudded with the\r\nsemi-submersible installation Dyvi Gamma on 13 August 1977 and drilled to TD at\r\n27871 m in the Hordaland Group. The progress of the drilling was very much\r\ndelayed due to technical problems on Dyvi Gamma. As a result, also hole\r\nproblems were increased due to very long exposure in open hole condition. Due\r\nto these problems the well bore was terminated after setting the 13 3/8"\r\ncasing instead of the plan, which was to drill down to the 9 5/8" casing\r\npoint. The well was drilled with seawater and gel all through. \u003c/p\u003e\r\n\r\n\u003cp\u003eSeveral thin sand beds were penetrated in\r\nthe Hordaland Group between 1610 m and 1737 m. Oil shows were recorded in the\r\nuppermost of these, from 1610 m to 1625 m.\u003c/p\u003e\r\n\r\n\u003cp\u003eNo cores were cut and no wire line fluid\r\nsamples taken in the well bore.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was suspended as dry on 27\r\nNovember 1977. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was performed\u003c/p\u003e\r\n\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"241","properties":{"OBJECTID":241,"wlbNpdidWellbore":246,"wlbName":"1/9-3 R","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 1/9-3 is located in the Feda Graben,\r\nclose to the UK border southwest in the Norwegian North Sea. The primary\r\nobjective of the well was to evaluate the Jurassic sandstones. The secondary\r\nobjective was to appraise and test the hydrocarbon bearing zones of Danian and\r\nMaastrichtian age (Shetland Group) encountered in 1/9-1. The well was drilled\r\nin two phases, of which Phase I is named 1/9-3 and Phase II is named 1/9-3 R.\r\nThis procedure was a requirement from the Norwegian Petroleum Directorate since\r\nDyvi Gamma came directly from the yard and had therefore not accumulated the\r\nexperience needed to drill the high pressure Jurassic well to a planned TD of\r\n5000 m. The re-entry 1/9-3 R was to be drilled with the rig Dyvi Beta.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 1/9-3 was re-entered (1/9-3 R) with\r\nthe semi-submersible installation Dyvi Beta on 27 May 1978 and drilled to TD at\r\n4570 m in the Late Jurassic Haugesund Formation. When running the 9 5/8"\r\ncasing problems occurred with stuck pipe. This resulted in severe delays, but\r\nthe casing was landed at planned depth. In the 8 1/2" hole the progress\r\nwas delayed due to hole problems with high pressure and mud weight combined\r\nwith lost returns. Tight hole and stuck pipe occurred on several occasions. Max\r\nmud weight was 2.04 g/cm. The well was drilled water based, but with several\r\nadditions of diesel from 9 5/8" casing depth and downwards, resulting in 1\r\n- 12 % diesel in the mud at all times below 3835 m.\u003c/p\u003e\r\n\r\n\u003cp\u003eSeveral problems arose during the logging\r\noperations, which in the end resulted in a poor suit of logs over the\r\nreservoir.\u003c/p\u003e\r\n\r\n\u003cp\u003eIn summary the problems were due to\r\nuncontrolled stretch in the logging cable, generally poor log quality,\r\nespecially for FDC/CNL logs, and difficult hole conditions with high pressure/temperature\r\nand excessive sticking. Logs that normally are run in combination had to be run\r\nseparately. This made petrophysical evaluation difficult, and several ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"242","properties":{"OBJECTID":242,"wlbNpdidWellbore":247,"wlbName":"1/9-4","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 1/9-4 was drilled on a salt diapir\r\nstructure in the Central Graben in the neighbourhood of the Norwegian - UK\r\nmedian line. The primary purpose was to test the Ekofisk and Tor formations of\r\nDanian and Maastrichtian age. Lower possible porous zones in chalk and Jurassic\r\nsands, if present, were secondary objectives.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 1/9-4 was spudded with the\r\nsemi-submersible installation Ross Rig on 13 August 1977 and drilled to TD at 3710\r\nm in Late Permian Zechstein salt. There were no serious drilling problems down\r\nto a depth of 3100 m. At 3100 m the bit-junksub assembly was lost in the hole. The\r\nhole was cemented back and sidetracked after the fishing attempts proved\r\nunsuccessful. After one unsuccessful sidetrack attempt the hole was sidetracked\r\nagain from 3041 m and drilled on to core point at 3122 m. When cutting core no 10\r\nthe bottom hole assembly got stuck and a long section of the BHA had to be left\r\nin the hole. After some unsuccessful attempts on jarring, the hole was cemented\r\nand sidetracked again, from 3059 m in the first sidetrack hole. This second sidetracked\r\nhole was drilled to a measured depth of 3353 m. At this point 7" liner was\r\nrun. 6" hole was drilled to a total measured depth of 3710 m with only\r\nminor problems and top of the salt was found at 3650 m. The 6" hole was\r\nlogged and plugged back. It was found necessary to perform a squeeze job around\r\nthe 7" liner shoe, but when attempting to pull out after this operation,\r\nthe BHA stuck just above the cementing stinger. Jarring did not free the pipe,\r\nand a cement plug was set above the fish. The well was drilled with high\r\nviscosity spud mud of pre-hydrated bentonite, lime, and caustic soda down to\r\n437 m and with Drispac/lime mud from 437 m to 2580 m. From 2580 m the lime was\r\nphased out and the remaining well to TD was drilled with a\r\nlignite/lignosulphonate gel mud. During abandonment an anchor chain broke in\r\nsevere weather. Th","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"243","properties":{"OBJECTID":243,"wlbNpdidWellbore":248,"wlbName":"1/9-5","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 1/9-5 was drilled in the Feda Graben\r\nin the southern North Sea, in the saddle between the Tommeliten Gamma-structure\r\nand the intrusive salt plug forming the Tommeliten Delta structure. The purpose\r\nof the well was to appraise the Tommeliten Gamma discovery made by 1/9-4 and to\r\ntest the hydrocarbon potential and reservoir quality of the Ekofisk and Tor\r\nformations.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 1/9-5 was spudded with the\r\njack-up installation Dyvi Beta on 3 October 1978 and drilled to TD at 3450 m in\r\nthe Late Cretaceous Hod Formation. The pipe got stuck at 3426 m during a\r\nclean-up trip. When trying to come loose the hook broke and the drill string\r\ndropped in the hole. This event caused material damage and rig shut-down for\r\nthree days, but nobody was injured. When fishing the drill string it came loose\r\nabove the jar but the rest of the BHA (approximately 260 m) was left in the\r\nhole. The well was drilled with spud mud down to 435 m, with a lime/"Morex"\r\nmud system from 435 m to 1377 m, with lime/"Morex"/Drispac mud from\r\n1377 m to 2725 m, and with lignosulphonate/lignite mud from 2725 m to TD. A lot\r\nof hole problems occurred in the 17 1/2" and 12 1/4" sections and\r\nthis was attributed to the lime/"Morex" mud system. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe Ekofisk Formation came in at 3207 m\r\nand the Tor Formation at 3282 m. No significant hydrocarbon shows were\r\nencountered in any section of the well.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eOne core was cut from 3215.5 to 3 233.5 m,\r\nproving a dry carbonate section. No wire line fluid samples were taken.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was permanently abandoned on 16\r\nDecember 1978 as a dry well.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"244","properties":{"OBJECTID":244,"wlbNpdidWellbore":249,"wlbName":"2/1-1","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 2/1-1 was drilled on the Cod Terrace\r\non the eastern margin of the Central Graben of the North Sea. The objectives\r\nwere Danian - Late Cretaceous limestones and possible Jurassic sandstone.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 2/1-1 was spudded with the\r\njack-up installation Ocean Tide on 28 August 1972 and drilled to TD at 4178 m\r\nin sediments believed to be of Late Jurassic age. The hole was drilled without\r\nmuch problem down to TD in the 8 1/2" section at 3886 m where logs were run\r\nand a 7" liner was set with shoe at 3885 m. A 5 7/8" hole was drilled\r\nto 4178 (TD) where the well kicked and the pipe got stuck. During killing\r\noperations returns were lost and circulation could not be re-established. The\r\nkick was most likely caused by a salt water flow from a Late Jurassic sand\r\nlense. When trying to back off the drill pipe twisted off, leaving a 340 m fish\r\nin the hole. A cement retainer was set and the well was plugged back to 3789 m.\r\nHence, no logs were run below 3886 m.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eOil shows (dull gold fluorescence with\r\nslow straw-yellow cut) were observed in the shales at the base of the Middle\r\nPalaeocene and at the top of the Danian limestone (3124 - 3178 m), especially\r\nat 3161 m where there was a good straw-yellow streaming cut (faster than the\r\nupper intervals) accompanied by a minor gas peak. In the lower part of the\r\nMaastrichtian limestone gas peaks with 10% C2+ components appeared. Oil shows\r\nwere recorded in limestone horizons in the Campanian and in the Berriasian.\r\nWeak fluorescence was observed also in thin sandstone lenses in the Late\r\nJurassic, above the kick-sand at TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eA core was cut from 3165.3 to 3179.1 m\r\n(10385 to 10430 ft) in the Danian limestone (Ekofisk Fo","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"245","properties":{"OBJECTID":245,"wlbNpdidWellbore":250,"wlbName":"2/1-2","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 2/1-2 is located on the Sørvestlandet\r\nHigh, ca 6 km northwest of the Gyda Field in The North Sea. The objective was\r\nto test possible Late Jurassic sands within a salt-induced structural high.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well is Reference Well for the Mandal\r\nand Ula Formations.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 2/1-2 was spudded with the\r\nsemi-submersible installation Nordskald on 14 December 1977 and drilled to TD at 3555 m, 15 m into Late Permian Zechstein anhydrite. The well was drilled\r\nwith seawater and gel down to 174 m, with Lime Drispac from 174 m to 3135 m,\r\nand with Lignosulphonate from 3551 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eFifty-two meter of Maureen Formation was\r\nencountered at 2692 m, directly overlying the Tor Formation at 2743.5 m. The\r\nCromer Knoll Group came in at 3121.5 m, and top Jurassic shales (Mandal\r\nFormation), at 3299 m. The Mandal Formation was seen as a potentially excellent\r\nsource rock for major oil, but was marginally mature on-structure. The well\r\npenetrated water-bearing Late Jurassic sandstone (Ula Formation) at a depth of\r\n3316 m. The sandstone was 30.5 m thick and had porosities of less than 10% and\r\npermeabilities less than 1 md. The well then penetrated 37.5 m of argillaceous\r\nMiddle Jurassic sandstone and 156 m of interbedded Triassic sandstones and\r\nsiltstones with occasional mudstones. No shows were observed in the well while\r\ndrilling.\u003c/p\u003e\r\n\r\n\u003cp\u003eOne full hole core was cut within the Ula\r\nFormation sandstone from 3318 to 3336 m. No wire line fluid samples were taken.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 26 February 1978 as a dry well.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was performed.\u003c/p\u003e\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"246","properties":{"OBJECTID":246,"wlbNpdidWellbore":251,"wlbName":"2/1-3","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 2/1-3 was drilled on the Cod Terrace\r\non the margin between the southern Vestland Arch and the Central Trough in the\r\nNorth Sea. The primary objective of the well was to test Late Jurassic\r\nsandstone within a fault sealed dip closure, against the downthrown side of a\r\nwesterly heading fault complex at the base of the Cretaceous. Triassic\r\nsandstone was a secondary objective.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 2/1-3 was spudded with the\r\nsemi-submersible installation SEDCO H on 3 November 1979 and drilled to TD at\r\n4297 in the Late Permian Zechstein Group. The well was drilled with Seawater\r\ndown to 625 m and with Lignosulphonate mud from 625 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eTop of the Tyne Group, Mandal Formation,\r\nwas encountered at 3791 m, with the Late Jurassic sandstone at 3819.5 m. The\r\nLate Jurassic sandstone reservoir was oil-bearing all through. The reservoir is\r\na 59.5 m thick homogeneous fine to medium grained sandstone with a porosity\r\nfrom 15% to 22%. The sandstone grades into a well cemented argillaceous\r\nsiltstone below. No oil/water contact was established. Oil shows were recorded\r\nin Tor Formation limestone at 3000 - 3005 m, throughout the Late Jurassic\r\nreservoir sandstone, and in Middle Jurassic Bryne Formation sandstone at 4020\r\nto 4040 m.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eFour cores were cut from 3823.0 to 3893.5\r\nm in the Ula Formation reservoir sandstones. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was permanently abandoned on 29\r\nMarch 1980 as an oil discovery.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eTesting\u003c/span\u003e\u003c/b\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThree drill stem tests were performed in the\r\nLate Jurassic sandstones. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyT","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"247","properties":{"OBJECTID":247,"wlbNpdidWellbore":252,"wlbName":"2/4-8","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 2/4-8 was drilled on the crest of\r\nthe Tor Discovery structure in the southern Norwegian North Sea. The principal\r\nobjective was to confirm the thick Danian-Cretaceous productive section present\r\nin the Amoco 2/5-1 well and to provide a means of evaluating the maximum\r\nanticipated productive section in the Tor Discovery. Jurassic sandstone was\r\nalso defined as principal objective, while secondary prospects could exist in\r\nPaleocene sands. Prognosed top Jurassic was at 3691 m (12110 ft) with planned\r\nTD at 4572 m (15000 ft). \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eAppraisal well 2/4-8 was spudded with the\r\njack-up installation Zapata Explorer on 25 November 1971. The original spud\r\nlocation was 56 deg 38' 15.6'' N, 03 deg 18' 48'' E. This hole was drilled to\r\n570 m at which point the well kicked and bridged off. The drill pipe became\r\nstuck at 486 m and the hole was abandoned with the top of fish at 323 m. The\r\nrig was moved 120 meters east where the well was re-spudded and drilled to\r\nfinal TD at 4078 m in the Permian Zechstein Group. The well was drilled with\r\nseawater and hi-vis mud down to 488 m, with drill aid / DAP (di-ammonium\r\nphosphate) mud from 488 m to 1623 m, with drill aid / gypsum mud from 1623 m to\r\n2211 m, with drill aid from 2211 m to 2984 m, with a lignosulphonate mud from\r\n2984 m to 3810 m, and with Drispac / salt saturated mud from 3810 m to TD.\r\nBelow 488 m 2 -6 % diesel was added to the mud.\u003c/p\u003e\r\n\r\n\u003cp\u003eAt 2946 m the well penetrated a 3 m fine\r\ngrained Paleocene sand with a calcite matrix. This sandstone exhibited a dull\r\nyellow fluorescence and a slow cut. Danian chalk was encountered at 2985 m and\r\nLate Cretaceous chalk was encountered at 3086 m. Gas and oil was tested from\r\nthe Danian - Late Cretaceous chalk. Continuous zones of oil shows were observed\r\non all cores down to 3203 m, below this depth shows were scattered.\u003c/p\u003e\r\n\r\n\u003cp\u003eTwenty cores with a total recovery of 176\r\nm core were cut in the interval 2985 to 3242 m in Danian and Late Cretaceous\r","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"248","properties":{"OBJECTID":248,"wlbNpdidWellbore":253,"wlbName":"2/4-9","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 2/4-9 was drilled on the\r\nsoutheast flank of the Albuskjell structure, 6 km southeast of the Shell 1/6-1\r\nwell, which was drilled on the saddle in the middle of the structure. The\r\nDanian Limestone was the expected pay zone, and if porosity was present, the\r\nLate Cretaceous Limestone was also expected to be hydrocarbon bearing. Planned\r\nTD was 3810 m (12500 ft).\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 2/4-9 was spudded with the jack-up\r\ninstallation Zapata Explorer on 13 August 1973 and drilled to TD at 3752 m in\r\nthe Late Cretaceous Hod Formation. The well was drilled and tested in 58 days,\r\nwithout significant technical problems. Deviation surveys were carried out down\r\nto 2448 m and the maximum deviation to this depth was 1.25 deg. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe Danian limestone was encountered at\r\n3214 m and the Late Cretaceous limestone at 3306 m. The Late Cretaceous\r\nlimestone yielded commercial oil and gas on two drill stem tests while the\r\nDanian limestone yielded no commercial hydrocarbons.\u003c/p\u003e\r\n\r\n\u003cp\u003eNo cores were cut and no wire line fluid\r\nsamples taken.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 9\r\nOctober 1973 as a gas and condensate appraisal. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eFour DST's were carried out in the chalk,\r\nDST 1 and 2 in the Late Cretaceous and DST 3 and 4 in the Danian. The results here\r\nare after acidizing: DST 1 from 3360 - 3368 m flowed 121 Sm3 oil and 97700 Sm3\r\ngas /day through a 96/64" choke. The oil gravity was 43 deg API and the\r\nGOR was 801 Sm3/Sm3. DST 2 from 3308 to 3359 m and 3360 to 3368 m flowed 461\r\nSm3 oil and 455900 Sm3 gas /day through chokes 20/64" + 24/64". The\r\noil gravity was 44 deg API and the GOR was 977 Sm3/Sm3. DST 3 from 3274 - 3283\r\nm and DST 4 from 3222 - 3225 flowed only small amounts of water with traces of\r\noil. \u003c/p\u003e\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"249","properties":{"OBJECTID":249,"wlbNpdidWellbore":254,"wlbName":"2/4-10","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 2/4-10 was drilled on an\r\nanticlinal structure, 4.8 km long and 2.4 km wide, lying approximately 8 km\r\nnorthwest of the centre of the Tor Field. The Danian limestone was the expected\r\npay zone, and if porosity was present, the Late Cretaceous Limestone could also\r\nbe hydrocarbon bearing. Prognosed top Danian was at 3139 m (10300 ft) with\r\nplanned TD at 3414 m (11200 ft).\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 2/4-10 was spudded with the jack-up\r\nrig Zapata Explorer on 13 October 1973 and drilled to TD at 3418 m in the Late\r\nCretaceous Tor Formation. The well was drilled and tested in 69 days, without\r\nsignificant technical problems. Deviation surveys were carried out down to 2451\r\nm and the maximum deviation to this depth was 2 deg. The well was drilled with\r\nsalt-water gel and Flosal down to 497 m, with Shale Trol from 497 to 2015 m,\r\nwith Unical (chromium-lignosulphonate) from 2015 m to 2819 m, and with Unical\r\nand Ligcon (caustisized lignite) from 2819 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eTop Danian limestone was encountered at\r\n3162 m and top Late Cretaceous limestone at 3293 m. The Danian Limestone tested\r\nonly small amounts of water and no oil, after acidization, on two drill stem\r\ntests. The Late Cretaceous Chalk produced oil, but with a very low GOR, and\r\nwith a high amount of water, which made its commerciality questionable. These\r\nfluid characteristics were furthermore very different from the 2/4-7 fluids\r\n(Tor discovery) and indicated 2/4-10 to be on a separate structure from the Tor\r\nField.\u003c/p\u003e\r\n\r\n\u003cp\u003eNo cores were cut and no wire line fluid\r\nsamples taken.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 20\r\nDecember 1973 as an oil discovery\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eSix DST's were conducted: DST 1 and DST 2\r\nin the Late Cretaceous and DST 3 to DST 6 in the Danian limestone. The results\r\ngiven here are after acidization: DST 1 from 3304 - 3322 m flowed 583 Sm3 oil,\r\n275 m3 water, and only 1150 Sm3 gas /day through a 24/64" choke. The oil\r\ngravity was","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"250","properties":{"OBJECTID":250,"wlbNpdidWellbore":255,"wlbName":"2/4-11","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 2/4-11 should evaluate the\r\nsouthern part of a northwest-southeast trending seismic high about 3.2 km long\r\nand 2.4 km wide. The well was drilled just south of the boundary between blocks\r\n2/1 and 2/4 about two km southeast of the 2/1-1 well. The objective formations\r\nwere the Danian-Late Cretaceous limestone in addition to sandstones of the\r\nJurassic, which had gas and condensate shows in the 2/1-1 well. Top Paleocene\r\nwas anticipated at 2972 m (9750 ft), top Danian at 3078 m (10100 ft), top Late\r\nCretaceous at 3277 m (10750 ft), and top Jurassic at 3962 m (13000 ft). Planned\r\nTD was at 4267 m (14000 ft).\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 2/4-11 was spudded with the jack-up\r\ninstallation Zapata Explorer on 25 December 1973 and drilled to TD at 4281 m in\r\nthe Late Permian Zechstein Group. Running 7" casing at 3838 m, the casing\r\ncould not get passed 3019 m. Pulling out of hole the casing stuck when 20\r\nstands were left. Eleven days were spent working on the fish before it came loose.\r\nThe hole was reamed and casing was set. Maximum hole deviation down to a depth\r\nof 2757 m was 4.75 deg, at 149 m. The well was drilled with spud mud (Seawater\r\ngel and Flosal) down to 321 m, with Shale Trol mud from 321 m to 2265 m, and\r\nwith a Lignosulphonate mud (Unical and Ligcon) from 2265 m to TD. Below 792 m\r\none to four percent diesel was added to the mud.\u003c/p\u003e\r\n\r\n\u003cp\u003eTop Paleocene was found at 2936 m, top\r\nDanian limestone at 3146 m, top Late Cretaceous limestone at 3268 m, top Early\r\nCretaceous was found at 3782 m, top Late Jurassic (Kimmeridgian) at 3968 m, and\r\ntop of the Permian was encountered at 4211 m. Sub-commercial amounts of oil was\r\ntested from the Danian and even smaller amounts from the Late Cretaceous. The\r\nJurassic section penetrated consisted of shale, claystone, and siltstone and\r\ncontained no reservoir rocks.\u003c/p\u003e\r\n\r\n\u003cp\u003eSource rock analyses of sidewall cores\r\nfrom the Jurassic showed TOC in the range 0.6 - 2% and vitrinite reflection\r\nfrom 0.78","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"251","properties":{"OBJECTID":251,"wlbNpdidWellbore":256,"wlbName":"2/4-12","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 2/4-12 was drilled on a location ca\r\n3 km west of the Ekofisk Field. The primary objective was to test the chalks in\r\nthe Late Cretaceous and Early Paleocene.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 2/4-12 was spudded with the\r\nsemi-submersible installation Ocean Viking on 28 July 1975 and drilled to TD at\r\n3383 m in the Late Cretaceous Tor Formation. No significant problems were\r\nencountered in the operations.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was found dry. There were no\r\nshows while drilling and electric logs showed low porosities and high water\r\nsaturations. Five cores were cut. Core 1 was cut in the basal part of the Våle\r\nFormation and topmost Ekofisk Formation. Cores 2 and 3 were cut in the Ekofisk\r\nFormation, and cores 4 and 5 in the Tor Formation. No wire line fluid samples\r\nwere taken.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 8\r\nSeptember 1975 as a dry well.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was performed\u003c/p\u003e\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"252","properties":{"OBJECTID":252,"wlbNpdidWellbore":257,"wlbName":"2/4-19 B","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 2/4-19 B was drilled on the Ekofisk\r\nField in the Southern North Sea.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 2/4-19 B was drilled from the Jacket\r\n12 legs installation Ekofisk B. It was spudded on 16 December 1975 and drilled\r\nto TD at 4605 m in Jurassic age sediments. The hole was lost below 3926 m (the\r\n7" casing shoe, in Early Cretaceous) after logging.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well penetrated top Jurassic at 4061\r\nm. The whole of the Jurassic section penetrated was mainly claystone, shale and\r\nlimestone. Four cores were cut: core 1 from 2974 to 2992.5 m, core 2 from\r\n3102.7 to 3113.8 m, and cores 3 and 4 from 3144.3 m to 3159.7 m. No wire line\r\nfluid samples were taken.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was plugged back to 3449 m and\r\nre-classed to development well. It was permanently abandoned 15 March 1976.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eTesting\u003c/span\u003e\u003c/b\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was tested from perforations at\r\n3006.5 m to 3009.6 m in the Danian Ekofisk Formation. Bottom hole samples were\r\ntaken, but no flow measurements were conducted. The DST temperature was 110 deg\r\nC, measured at 2840.7 m\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003e\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"253","properties":{"OBJECTID":253,"wlbNpdidWellbore":258,"wlbName":"2/5-3","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 2/5-3 was drilled ca 8 km southeast\r\nof the Tor Field. The primary target was top Danian chalk. Secondary targets\r\nwere top Paleocene and base chalk at 3551 m (11650 ft). Planned total depth was\r\n3597 m (11800 ft).\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell was spudded with the jack-up\r\ninstallation Zapata Explorer on 2 April 1972 and drilled to TD at 3731 m in the\r\nLate Permian Zechstein Group. \u003c/p\u003e\r\n\r\n\u003cp\u003eTop Paleocene was encountered at 2929 m,\r\ntop Ekofisk Formation at 3037 m, top Tor Formation at 3121 m, and top Hod\r\nFormation at 3481 m. First show was reported in a limestone stringer at 2259 m.\r\nOccasional oils shows, in limestone stringers, were reported in the interval\r\n2604 to 2877 m. The top 3 m of the Paleocene (Balder Formation) was silty and\r\nhad good oil shows. Oil was found by drill stem testing in the Ekofisk and Tor\r\nFormations. Shows continued down to 3261 m in the Tor Formation.\u003c/p\u003e\r\n\r\n\u003cp\u003eFifteen conventional cores were cut in\r\nthe Ekofisk and Tor Formations, recovering a total length of 123.3 m core.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was suspended on 15 June 1972 as\r\nan oil discovery.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThree zones were drill stem tested. The\r\nfollowing results are after acidization: \u003c/p\u003e\r\n\r\n\u003cp\u003eDST 1 tested the interval 3386 - 3395 m\r\nin the lower part of the Tor Formation and flowed 21 m3 water /day.\u003c/p\u003e\r\n\r\n\u003cp\u003eDST 2 tested the interval 3120 - 3191 m\r\nin the upper part of the Tor Formation. Average flow parameters at maximum\r\nchoke, 40/64", was 682 Sm3 oil and 340400 Sm3 gas /day. The oil gravity\r\nwas 36 deg API and the GOR was 463 Sm3/Sm3. The GOR on smaller choke sizes was\r\nsignificantly lower, down to 233 Sm3/Sm3 on a 16/64 "choke.\u003c/p\u003e\r\n\r\n\u003cp\u003eDST 3 tested the interval 3053 - 3065 m\r\nin the Ekofisk Formation and flowed on average 682 Sm3 oil and 141330 Sm3 gas\r\n/day on a 32/64" choke. The water production during this flow decreased\r\nfrom 57 to 17.5 m3 /day and the GOR decreased from 213 to 179 Sm3/Sm3. The oil\r\ngravity was 38.2 deg A","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"254","properties":{"OBJECTID":254,"wlbNpdidWellbore":259,"wlbName":"2/5-4","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 2/5-4 was drilled ca 21 km\r\nsoutheast of the Tor Field in the southern Norwegian North Sea. The primary\r\ntargets were Paleocene prognosed at 2914 m (9560 ft), and Danian Carbonate\r\nprognosed at 3011 (9880 ft).\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 2/5-4 was spudded with the jack-up\r\ninstallation Zapata Explorer on 3 November 1972 and drilled to TD at 3490 m in\r\nthe Late Cretaceous Hod Formation. No significant technical problems were\r\nreported from the operations. The well was drilled with seawater and hi-vis mud\r\ndown to 395 m, with an XC polymer, Shale Trol mud from 395 m to 2743 m, and\r\nwith Chromium-lignosulphonate (Unical) / seawater mud from 2743 m to TD. From 1\r\nto 6 % diesel addition was used all through.\u003c/p\u003e\r\n\r\n\u003cp\u003eTop Paleocene (Balder Formation) was\r\nencountered at 2928 m, top Danian chalk (Ekofisk Formation) at 3039 m, top\r\nMaastrichtian chalk (Tor Formation) at 3131 m, and top Campanian chalk (Hod\r\nFormation) at 3420 m. \u003c/p\u003e\r\n\r\n\u003cp\u003eFirst show (appearance of C2+ on\r\nchromatograph) was in shale at 2883 m. Thin sandstone stringers were penetrated\r\nin the Paleocene section, but no shows were recorded in these. Oil shows were\r\nrecorded in the top of the Danian chalk at 3042 - 3063 m, in the top of the Tor\r\nFormation at 3133 - 3167 m, and in the Hod Formation at 3435 - 3459 m. Oil was\r\nconfirmed by testing in the top of the Tor Formation.\u003c/p\u003e\r\n\r\n\u003cp\u003eFive short cores were taken with the\r\nSchlumberger core slicer. Core no 1 was taken at 3441.5 m in the Hod Formation;\r\ncores no 2, 4, and 5 were cut at 3137.9 - 3159.6 m in the Tor Formation, and\r\ncore no 3 was taken at 3051.7 - 3052.6 m in the Ekofisk Formation. The cores\r\nare no longer available from the NPD. No fluid sample was taken on wire line.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 31\r\nOctober as an oil discovery.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eTwo drill stem tests were performed. The\r\nfollowing results are after acidizing:\u003c/p\u003e\r\n\r\n\u003cp\u003eDST 1 tested the interval 3137 - 3170 in\r\nthe top of t","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"255","properties":{"OBJECTID":255,"wlbNpdidWellbore":260,"wlbName":"2/5-5","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 2/5-5 was drilled ca 2 km southwest\r\nof the 2/5-3 S ør øst Tor Discovery well in the southern Norwegian North Sea.\r\nIt was drilled to appraise the S ør øst Tor Discovery \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eAppraisal well 2/5-5 was spudded with the\r\njack-up installation Zapata Explorer on 9 December 1972 and drilled to TD at\r\n3456 m in the Late Cretaceous Tor Formation.\u003c/p\u003e\r\n\r\n\u003cp\u003eTop Paleocene was encountered at 3058 m,\r\ntop Danian chalk (Ekofisk Formation) at 3176 m, and top Maastrichtian chalk\r\n(Tor Formation) at 3274 m. The only oil show reported above top Cretaceous was\r\nin thin dolomite stringers at 2940 - 2950 m. Oil shows were recorded in the Tor\r\nFormation from the top and down to 3383 m. Oil was confirmed by testing in the\r\nTor Formation.\u003c/p\u003e\r\n\r\n\u003cp\u003eTwo cores were cut in the interval 3284 -\r\n3321 m in the Tor Formation. No wire line fluid sample was taken.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 9\r\nFebruary 1973 as an oil appraisal.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThree drill stem tests were conducted in\r\nthe Tor Formation. The following results are after acidizing: \u003c/p\u003e\r\n\r\n\u003cp\u003eDST 1 tested the interval 3428 - 3437 m\r\nin. At the end of the flow period only load water had come to surface and the\r\npressure had dropped to zero. \u003c/p\u003e\r\n\r\n\u003cp\u003eDST 2 tested the interval 3355 - 3366 m.\r\nAfter 31 hours flow only acid and water cushion was produced to surface.\u003c/p\u003e\r\n\r\n\u003cp\u003eDST 3 tested the intervals 3297 to 3298 m\r\n+ 3307 to 3308 + 3312.9 to 3313.5 m. This test produced 72 Sm3 oil, 12430 Sm3\r\ngas, and 195 m3 water /day on a 64/64" choke. The GOR was 171 Sm3/Sm3 and\r\nthe oil gravity was 39.4 deg API.\u003c/p\u003e\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"256","properties":{"OBJECTID":256,"wlbNpdidWellbore":261,"wlbName":"2/5-6","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 2/5-6 was drilled on the Siv\r\nstructure, only 800 m northeast of the 2/5-4 discovery well. The Siv structure\r\nis a north-south trending anticline. The primary objective of well 2/5-6 was to\r\nestablish the possibility of Jurassic sands being present along the west side\r\nof the Mandal High and to evaluate the hydrocarbon potential of these sands on\r\nthe Siv structure. Sands of this age had previously been encountered in the BP\r\nblock 7/12 further to the north. In addition, the well was planned to appraise\r\nthe Chalk reservoirs found to be oil-bearing by Amoco well 2/5-4.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 2/5-6 was spudded with the\r\nsemi-submersible installation Norskald on 14 May 1978 and drilled to TD at 4132\r\nm in the Triassic Skagerrak Formation. A bentonite slurry used while drilling\r\nthe first two intervals, 30" casing was set at 166 m and 20" casing\r\nat 540 m. The 17 1/2" hole was drilled using a seawater native solids mud.\r\nProblems were encountered as casing point was approached, sloughing shale and\r\ntight hole proved troublesome and the mud weight was increased to 10.6 lb/gal\r\nbefore running 13 3/8" casing to 1852 m. The 12 1/4" hole was drilled\r\ninitially with a gypsum CMC mud. Tight hole was a significant problem until a\r\ndepth of approximately 2900 m. At 2950 m the mud was converted to a dispersed\r\nlignosulphonate system to obtain more stable rheological properties. This mud\r\nwas used until a depth of 3967 m. Tight hole was experienced on trips at a\r\ndepth of 2000 m. The pipe was stuck at 3640 m and a fish was left in the hole.\r\nThe 9 5/8" casing was set above the fish at a depth of 3560 m and a\r\ntechnical sidetrack was performed. The 8 1/2" hole was drilled using the\r\nsame mud to a depth of 3967 m. At this point, in a Middle Jurassic sand, a salt\r\nwater flow high in magnesium and calcium delayed operations considerably. The\r\nmud was converted to a brine polymer type system and the mud weight was raised\r\nto ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"257","properties":{"OBJECTID":257,"wlbNpdidWellbore":262,"wlbName":"2/7-3","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 2/7-3, was drilled on the southern\r\ncompartment of the Eldfisk structure in the North Sea. The Eldfisk structure is\r\na NNW-SSE trending partly salt-related anticlinal structure located between the\r\nValhall and Embla fields to the south and the Ekofisk Field to the north. The\r\nprimary objectives were to test the Danian Limestone, and the possibility of\r\nJurassic sandstone development on the crest of the Eldfisk structure. Both\r\nobjectives were expected to be ca 120 m thick. The Late Cretaceous carbonate,\r\nlower Cretaceous sandstones and Triassic sandstones were secondary objectives.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 2/7-3 was spudded with the jack-up\r\ninstallation Orion on the 14 April 1972 and drilled to TD at 4359 m in the Permian\r\nZechstein Group. Note that the Daily Report records Decca final fix as 56° 23' 01.7\"N,\r\n03° 14' 44.6\"E, 60 meters off desired location, while other parts of the Completion Report\r\nseems to record the coordinates of the slightly different planned well location.\r\nThe well was drilled with seawater and hi-vis sweeps down to 482\r\nm, with gypsum-CMC lignosulphonate mud from 482 m to 3195 m, and with salt\r\nsaturated gypsum-CMC lignosulphonate mud from 3195 m to TD. Between 482 m and\r\nTD diesel was added to the mud.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe Danian section was 90 m thick, highly\r\nfractured, and yielded commercial quantities of oil. Logs and two drill stem\r\ntests (DST 1 and DST 2) in the Late Cretaceous rocks indicated low porosity and\r\npermeability. One hundred and fifty gross meter of Jurassic sandstones was\r\npenetrated in the well. Log analysis indicated the sands are very shaly and\r\nsilty. Three of the sidewall cores from this interval were described as hard,\r\nblack shale and the fourth as a very calcareous sandstone. Although the logs\r","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"258","properties":{"OBJECTID":258,"wlbNpdidWellbore":263,"wlbName":"2/7-4","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 2/7-4 is located in the southern\r\npart of the Norwegian North Sea and ca 10 km south east of the Ekofisk Field.\r\nThe primary objective was the Danian Chalk, expected to be 90 m thick and\r\npossibly completely hydrocarbon bearing.\u003c/p\u003e\r\n\r\n\u003cp\u003eSecondary objective was Late Cretaceous\r\ncarbonates, especially in the upper part, which could be oil bearing in\r\ncommunication with the Danian. Planned TD was at 3353 m in the Late Cretaceous.\r\nIn the event that hydrocarbon shows were still evident at the proposed TD the\r\nwell would be deepened until potential productive zones were completely\r\npenetrated.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 2/7-4 was spudded with the\r\nsemi-submersible installation Ocean Viking on 23 June 1972 and drilled to TD at\r\n3356 m in the Late Cretaceous Tor Formation. The well was drilled without\r\nsignificant problems.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe "Danian Chalk" (Ekofisk\r\nFormation) was encountered at 3096 m, and the Late Cretaceous Tor Formation at\r\n3186 m. Both formations were oil bearing. DST's and logs indicate oil down to\r\n3225 m, while the deepest test at 3291 - 3266 m produced water, some gas, and\r\ntrace oil. Oil shows were recorded on cores in the interval 3133 m to 3246 m.\u003c/p\u003e\r\n\r\n\u003cp\u003eTwelve cores were cut from 3116 m to 3264\r\nin the Ekofisk and Tor Formations. No wire line fluid samples taken.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 3\r\nSeptember 1972 on as an oil discovery.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eSix DST's were conducted in the Ekofisk\r\nand Tor Formations. Maximum production data after acid treatment follows: DST 1\r\ntested the interval 3292 - 3266 m in the Tor Formation and produced 67 m3/day\r\nwater, 2800 Sm3/day gas, and trace oil. DST 2 tested the interval 3197 - 3234 m\r\nin the Tor Formation and produced 1054 Sm3 oil and 273600 Sm3 gas /day on a\r\n44/64" choke. The GOR was 260 Sm3/Sm3 and the oil gravity was 37.7 deg\r\nAPI. DST 3 tested the interval 3149 - 3170 m in the Ekofisk Formation and\r\nproduced 200 Sm3 oil ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"259","properties":{"OBJECTID":259,"wlbNpdidWellbore":264,"wlbName":"2/7-5","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 2/7-5 was drilled ca 4.5 km\r\nnorth-northeast of the 2/7-4 well, which found oil in the Ekofisk and Tor\r\nFormations, the Edda Discovery. The objective of the 2/7-5 well was to test the\r\nEkofisk and Tor Formations in order to appraise the extension of this\r\ndiscovery.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eAppraisal well 2/7-5 was spudded with the\r\nsemi-submersible installation Ocean Viking on 3 September 1972 and drilled to\r\nTD at 3353 m in the Late Cretaceous Tor Formation. The well was drilled water\r\nbased with 3 - 6 % oil addition below 1217 m.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe Ekofisk Formation was encountered at\r\n3110 m, and the Tor Formation at 3205 m. Both formations appeared to be\r\nhydrocarbon bearing, but the water saturation was high and the permeability was\r\ngenerally low, which probably explained the low flow rates of the zones tested.\r\n\u003c/p\u003e\r\n\r\n\u003cp\u003eEight conventional cores were cut in the\r\ninterval 3120 - 3158 m in the Ekofisk Formation, and another five cores were\r\ncut in the interval 3219 - 3300 m in the Tor Formation. The cores were reported\r\nto bleed gas and oil. Scattered shows (fluorescence) were observed from top of\r\nthe cored interval and down to 3285 m in the deepest core (core 13).\u00A0 No wire\r\nline fluid samples were taken.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 1\r\nJanuary 1973 as a dry well with shows.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eSeveral drill stem tests were conducted\r\nin the limestone and chalk of the Ekofisk and Tor Formations. Many were\r\nunsuccessful. Of the technically successful tests DST 1 from 3274 m to 3293 m\r\nand DST 2 from 3225 - 3237 m flowed water. DST 3 from 3210 - 3219 m flowed\r\nwater with gas and trace of oil. DST 4 from 3160 - 3185 m and DST 5 from 3120 -\r\n3130 m flowed minor amounts of gas and water.\u003c/p\u003e\r\n\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"260","properties":{"OBJECTID":260,"wlbNpdidWellbore":265,"wlbName":"2/7-6","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 2/7-6, was drilled on the northern\r\npart of the Eldfisk structure in the North Sea. The primary objective was to\r\ntest the Danian Limestone, and secondarily to test for possible further\r\nhydrocarbons in the Late Cretaceous of the Eldfisk structure.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 2/7-6 was spudded with the semi-submersible\r\ninstallation Ocean Viking on 31 March 1973 and drilled to TD at 3381 m in the Early\r\nCretaceous Cromer Knoll Group. The well was drilled with seawater and hi-vis sweeps\r\ndown to 488 m and with gypsum-lignosulphonate mud from 488 m to TD. Diesel was\r\nadded to the mud below 488 m.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe Danian Ekofisk Formation and the\r\nunderlying Tor Formation were found oil bearing and tested to yield commercial\r\nquantities of oil from top at 2911 m to 3078 m.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo cores were cut and no fluid samples\r\nwere taken on wire line.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was permanently abandoned on 8\r\nJune 1973 as an oil appraisal well.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eTesting\u003c/span\u003e\u003c/b\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eFour drill stem tests were performed, two\r\nin the Ekofisk Formation and two in the Tor Formation.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eDST1 tested the interval 2973 to 2987 m\r\nand produced after acidization 46 Sm3 oil and 12400 Sm3 gas /day through a\r\n96/64" choke. The GOR was 274 Sm3/Sm3, the gas gravity was 0.699 (air =\r\n1), and the oil gravity was 36.6°API.\u00A0\u00A0 \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eDST2 tested the interval 3069 to 3078 m\r\nand produced after acidization 158 Sm3 oil and 56900 Sm3 gas /day through a\r\n96/64" choke. The GOR was 359 Sm3/Sm3 and th","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"261","properties":{"OBJECTID":261,"wlbNpdidWellbore":266,"wlbName":"2/7-7","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 2/7-7, was drilled to appraise the southern\r\npart of the Eldfisk structure in North Sea. The primary objective was to test\r\nthe Danian Limestone, expected to be about 120 m thick. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 2/7-7 was spudded with the\r\nsemi-submersible installation Ocean Viking on 2 January 1973 and drilled to TD\r\nat 3084 m in the Early Cretaceous Rødby Formation. The well was drilled with seawater\r\nand hi-vis sweeps down to 497 m and with gypsum/lignosulphonate mud from 497 m\r\nto TD. 4-6% diesel additive was used below 497 m.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe Danian Limestone was found to be\r\nhighly fractured, only3 0 m thick, and yielded commercial quantities of oil and\r\ngas on one drill stem test. The Late Cretaceous, which was 195 m thick, was\r\nalso found to contain hydrocarbons, and yielded commercial amounts of oil and\r\ngas on two out of three drill stem tests. The Danian Limestone and the upper\r\npart of the Late Cretaceous were thinner than expected due to a fault throwing\r\nCampanian on Turonian rocks.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo cores were cut and no fluid samples\r\nwere taken.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was permanently abandoned on 29\r\nMarch 1973 as an oil appraisal.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eTesting\u003c/span\u003e\u003c/b\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eFour intervals in the chalk section were\r\nperforated and tested\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eDST's 1 and 2 tested the interval 2911 to\r\n2925. The interval gave a weak flow with headed oil + gas. The oil gravity was\r\nmeasured to 36.2 °API.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eDST 3 tested the interval 2838 to 2905 m.\r\nThe interval produced after acidiz","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"262","properties":{"OBJECTID":262,"wlbNpdidWellbore":267,"wlbName":"2/7-8","wlbHistory":"\r\n\r\n\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 2/7-8 is located In the Feda Graben\r\nof the southern North Sea, some 3 km west of the Eldfisk Field. It was drilled\r\non the East Eldfisk Structure, and the main objective was to test the Danian\r\nLimestone. Secondary objective was to test the Late Cretaceous Chalk, which\r\ncould by hydrocarbon bearing if porosity is present.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 2/7-8 was spudded with the jack-up\r\ninstallation Zapata Explorer on 8 June 1973 and drilled to TD at 3318 m in the\r\nLate Cretaceous Hod Formation. The well was drilled with seawater and hi-vis\r\nslugs down to 1220 m, and with a lignosulphonate mud (UNI-CAL / Caustic) from\r\n1220 m to TD. According to the mud program the section below 1220 m was drilled\r\nwith 4% diesel in the mud.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe Danian Limestone, which was expected\r\nto be 100 m thick with 38 m of net pay, was found to be much thinner than the\r\nother wells on Eldfisk, and was only 9 m thick. It was also less fractured than\r\nother wells on Eldfisk, but still yielded commercial quantities of oil and gas,\r\nafter acidization, over the total interval on the third of three drill stem\r\ntests. This test included the top 23 m of the Late Cretaceous (Maastrichtian). The\r\nremaining tests below this interval, also in the Maastrichtian, did not produce\r\noil or gas in commercial amounts. The truncated Danian, the lack of fracturing\r\nand secondarily porosity, and the fact that the produced oil was heavier than the\r\noils on the main Eldfisk structure to the west, suggested that East Eldfisk structure\r\nis not in communication with the main Eldfisk structure.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo cores were cut and no wire line fluid\r\nsamples were taken.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp cla","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"263","properties":{"OBJECTID":263,"wlbNpdidWellbore":268,"wlbName":"2/7-9","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 2/7-9 is located in the Ål Basin south\r\nof the Eldfisk structure in the southern North Sea. The main purpose of the\r\nwell was to test Danian -Cretaceous limestone and Jurassic sandstone on a\r\nnorth-south trending anticline 6 - 8 km south of Eldfisk, where these intervals\r\nhad proven commercial oil in several wells.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 2/7-9 was spudded with the\r\njack-up installation Zapata Nordic on 25 December 1973 and drilled to TD 4448 m\r\nin Devonian sediments. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 2/7-9 was spudded with the jack-up installation Zapata Nordic on 25 December 1973 and drilled to TD 4448 m in Devonian sediments.\r\nThe Danian Limestone (Ekofisk Formation) came in at 3086 m. It was expected to be 90 m thick while 77 m was found.\r\nThe Late Cretaceous Chalk (Cromer Knoll Group) was anticipated to be 695 m thick, but a greater thickness of 800 m was found.\r\nGood shows were seen in both intervals, but no hydrocarbons were produced when tested.\r\nSands initially dated Late Jurassic were encountered at 4313 m and proved to be hydrocarbon bearing with a 111 m pay section with average porosity of 13% and 55% oil saturation.\r\nA clear OWC was found at 4424 m.These sands have later been interpreted as of Devonian age.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo cores were cut and no wire line fluid\r\nsamples were taken.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was permanently abandoned on 10\r\nApril 1974.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eTesting\u003c/span\u003e\u003c/b\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThree drill stem tests were conducted in\r\nthe well.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eDST 1 tested the interval 4313 to 4356 m\r\nin the Devonian sandstone","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"264","properties":{"OBJECTID":264,"wlbNpdidWellbore":269,"wlbName":"2/7-10","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 2/7-10 was drilled on the Edda\r\nstructure in the southern North Sea. The principal zone of interest was the\r\nDanian Limestone, which was found hydrocarbon-bearing ca 13 km to the northeast\r\non the Ekofisk field, and which held commercial quantities of oil and gas in\r\nthe 2/7-4 well on the Edda structure just over a mile to the southeast. The\r\nDanian sequence was expected to be ca 90 m thick. The Late Cretaceous was a\r\nsecondary objective and could contain hydrocarbons if porosity was present.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 2/7-10 was spudded with the jack-up\r\ninstallation Zapata Nordic on 6 October 1973 and drilled to TD at 3370 m in the\r\nLate Cretaceous Tor Formation. Bad weather caused some technical problems and\r\ndelayed operations for some days. The well was drilled water based, but with\r\n3-4 % addition of oil below 2691 m. The Danian limestone sequence (Ekofisk\r\nFormation) was encountered at 3191 m. It was 90 m thick as prognosed but with\r\nonly 6 m of gross pay, which, after acidization, yielded nothing commercial.\r\nThe equivalent interval in the 2/7-4 well produced commercial oil and gas on\r\nthe deepest of three drill stem tests. The Late Cretaceous Tor Formation,\r\nhowever, was found to have 31 m of potential pay, which correlates well with\r\nthe 2/7-4 interval. It flowed commercial amounts of oil and gas after acid, on\r\ntwo drill stem tests. The upper one of these compared well with the equivalent\r\nhorizon in the 2/7-4, although less productive. Shows were recorded from top of\r\nthe Ekofisk and all through the limestone/chalk section down to ca 3338 m in\r\nthe Tor Formation.\u003c/p\u003e\r\n\r\n\u003cp\u003eNo cores were cut and no wire line fluid\r\nsamples taken in the 2/7-10 well\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 5\r\nDecember 1973 as an oil appraisal.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eFive successful DST's were carried out in\r\nthe well. Maximum flow data after acidization follows:\u00A0 DST 1 from the interval\r\n3313 - 3322 m (Tor Formation) produced 233 m3 water","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"265","properties":{"OBJECTID":265,"wlbNpdidWellbore":270,"wlbName":"2/7-11","wlbHistory":"\u003chtml\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 2/7-11 was drilled on the Lindesnes\r\nRidge in the North Sea, between the Eldfisk and Valhall fields. The primary objective\r\nwas to evaluate the Danian.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 2/7-11 was spudded with the semi-submersible\r\ninstallation Ocean Viking on 24 February 1975 and drilled to TD at 3377 m in\r\nthe Early Cretaceous Rødby Formation. No significant problem was encountered in\r\nthe operations.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well encountered no porosity or\r\nhydrocarbon accumulations of reservoir qualities. There were shows in\r\nEocene-Paleocene.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo cores were cut and no fluid samples\r\nwere taken.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was permanently abandoned on 30\r\nMarch 1975 as a dry well.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eTesting\u003c/span\u003e\u003c/b\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo drill stem test was performed. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"266","properties":{"OBJECTID":266,"wlbNpdidWellbore":271,"wlbName":"2/7-12","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 2/7-12 was drilled on an\r\nintrusive salt plug in the upper left corner of the block, some km west of the\r\nEkofisk and Edda fields in the Southern Norwegian North Sea. The salt plug is\r\nlocated in the cross-junction between the four blocks 1/6, 1/9, 2/4, and 2/7.\r\nThe objective was to establish if Danian - Late Cretaceous carbonates were\r\npresent on the salt plug. If present the carbonates would be evaluated. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 2/7-12 was spudded with the semi-submersible\r\ninstallation Dyvi Beta on 17 December 1978 and drilled to TD at 1832 m in the\r\nLate Permian Zechstein Group. The well was drilled with salt-based mud,\r\npossibly with some diesel addition according to geochemical analyses, in the\r\ninterval from 1402 m to TD. Several thin gas charged siltstone stringers were\r\npenetrated between 433 m and 835 m.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe salt (Permian Zechstein Group) was\r\nencountered at 1686 m. The well did not encounter any Danian -Late Cretaceous\r\ncarbonates on top of the salt. Oil shows (fluorescence, cut, stain or\r\ncombinations) were recorded on SWC's and cuttings at 114.5 - 445 m (sandstone),\r\n731 - 810 m (claystone with trace of fine sandstone), and scattered on\r\nclaystone, shale, and limestone from 1469 m to 1679 m. The resistivity log indicated\r\na probable hydrocarbon zone from 416 to 433 m in a shallow sand. It was not\r\npossible to calculate reliable porosity from the sonic log, but a DST confirmed\r\nminor amounts of oil.\u003c/p\u003e\r\n\r\n\u003cp\u003eNinety sidewall cores were attempted and\r\nseventy-one were recovered from the overall interval 1417.3 to 173.7 m. No\r\nconventional cores were cut and no wire line fluid samples taken in this well.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 30\r\nJanuary 1979 as a dry well with shows.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eOne drill stem test was performed through\r\nperforations at 416.7 - 425.8 m. The tool was open 22 minutes; shut in one hour\r\nand 58 minutes, open 3 hours and shut in 3 hours and 58 minutes. No ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"267","properties":{"OBJECTID":267,"wlbNpdidWellbore":272,"wlbName":"2/7-13","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eExploration well 2/7-13 was drilled to\r\nthe East of an intrusive salt dome in the Ekofisk area of the Norwegian sector\r\nof the North Sea. The structure had already been investigated by wells 1/9-4\r\nand 1/9-5 to the west, and also above the salt dome in 2/7-12. The Danian/Late\r\nCretaceous was the primary objective. A secondary objective was the possibility\r\nof a reservoir on the flank of the dome with the salt forming a seal.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 2/7-13 was spudded with the jack-up\r\ninstallation Dyvi Beta on 1 February 1979 and drilled to TD at 3388 m in the\r\nEarly Cretaceous Sola Formation. No significant problems were reported from the\r\noperations. The well was drilled with spud mud/Drispac/seawater down to 1309 m,\r\nand with seawater/Drispac from 1309 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eHigher hydrocarbon gasses were observed\r\nfrom 975 m to 1113 m. Very poor fluorescence was noted in the clay and\r\noccasional limestone in the same interval. Poor shows occurred in limestones at\r\n2210 - 2225 m and 2265 - 2274 m, and also in dolomite limestone stringers from\r\n2387 - 2591 m. The Danian and Cretaceous limestones also gave poor oil shows\r\nwith some staining in the Ekofisk Formation from 2719 to 2801 m. Five\r\nconventional cores with a total of 22 m recovered were taken in this zone from\r\n2725.5 m to 2790 m. No wire line fluid samples were taken.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 21\r\nApril 1979 as a dry well with shows.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eFour intervals in the 8 1/2" section\r\nwere tested through 7" liner. DST 1 tested the Hidra Formation from 3188\r\nto 3257 m and produced 504 Sm3 water with 1.5% oil/day, DST 2 tested the Hod\r\nFormation from 3042 to 3085 m and produced 1441 Sm3 water with ca 3000 Sm3\r\ngas/day, DST 3 tested the Ekofisk Formation from 2740 to 2774 m and 2793.5 to\r\n2807 m, and DST 4 tested the Ekofisk Formation from 2697.5 to 2729 m. DST 3 and\r\nDST 4 produced only small amounts of water (1 Sm3/day and 69 Sm3/day,\r\nrespect","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"268","properties":{"OBJECTID":268,"wlbNpdidWellbore":273,"wlbName":"2/8-4","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 2/8-4 was drilled on the Valhall\r\nstructure in the Southern North Sea\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 2/8-4 was spudded with the jack-up\r\ninstallation Zapata Explorer on 28 April 1973 and drilled to TD at 2852 m. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eTop Shetland Group was encountered with\r\noil shows at 2577 m. The Shetland Group had only one meter of Tor Formation on\r\ntop of the Hod Formation.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThree very short cores were cut: core 1\r\nfrom 2607.3 to 2698.2 m, core 2 from 2597.8 to 2598.7 m, and core 3 from 2584.1\r\nm to 2585 m. No wire line fluid samples were taken.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was permanently abandoned on 7\r\nJune 1973, initially as a dry well with shows. After the 2/8-6 Valhall discovery\r\nwell two years later it was re-classified to oil appraisal well.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eTesting\u003c/span\u003e\u003c/b\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eTwo drill stem tests were performed. In\r\nboth tests the chalk was stimulated by acid.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eDST 1 tested the interval 2603 to 2622.5\r\nm. The test produced 5.7 m3 load water during a 6.5 hrs flow\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eDST 2 tested the interval 2578.6 to\r\n2587.8 m. This test produced 2.5 m3 load water and 0.5 Sm3 26 deg API oil\r\nduring a 12 hrs flow. \u003c/span\u003e\u003c/p\u003e\r\n\u003e\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"269","properties":{"OBJECTID":269,"wlbNpdidWellbore":274,"wlbName":"7120/10-1","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 7120/10-1 is located in the Troms I area in the southwestern part of the Hammerfest Basin, close to the Troms-Finnmark\r\nFault Complex. The main objective of the well was to test the Middle to Early\r\nJurassic sands of the B-prospect located in the south-eastern part of the block\r\n\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was spudded with the\r\nsemi-submersible installation Zapata Ugland on 10 September 1984 and drilled to\r\nTD at 2000 m in the Late Triassic. While drilling the 36" hole a boulder\r\nzone was encountered at 210 m to 248 m, which made it difficult to set the\r\n30" casing. When pressure testing the seal assembly before drilling out of\r\nthe 9 5/8" casing shoe, a leak was found in the well head connector. The\r\nleakage was repaired before drilling of the 8 1/2" hole section. The well\r\nwas drilled using gel/seawater down to 534 m, with bentonite/CMC from 534 m to\r\n1302 m, and with gel/lignosulphonate/seawater from 1302 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eNo hydrocarbons were encountered in the\r\nwell. No potential reservoir sands were present above the Middle Jurassic. In\r\nthe Middle Jurassic to Top Triassic interval a net 200 m of good quality\r\npotential reservoir sandstone was penetrated. \u003c/p\u003e\r\n\r\n\u003cp\u003eOne core was cut in the Middle Jurassic\r\nStø Formation from 1570 m to 1584 m. Twenty-two RFT pressure readings were\r\nobtained from 1570 m to 1589 m, showing a saltwater pressure gradient. A fluid\r\nsample was taken at 1573.9 m. The sample contained mud filtrate without any gas\r\nor any smell or sign of hydrocarbons. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 8\r\nSeptember 1984 as a dry hole.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was performed\u003c/p\u003e\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"270","properties":{"OBJECTID":270,"wlbNpdidWellbore":275,"wlbName":"2/8-5","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 2/8-5 is located within closure of\r\nthe large NNW-SSE trending Valhall structure, close to well 2/8-2 and ca 8 km\r\nsouth of the 2/5-3 Sørøst Tor Discovery. The primary target was\r\nDanian/Maastrichtian chalk/limestones. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eExploration well 2/8-5 was spudded with\r\nthe jack-up installation Zapata Explorer on 11 April 1974 and drilled to TD at\r\n3304 m in the Early Cretaceous Rødby Formation. Some problems with lost\r\ncirculation were experienced at 1618 m. At 1909 m in the Hordaland Group a gas\r\nkick was taken. Otherwise drilling went without significant problems.\u003c/p\u003e\r\n\r\n\u003cp\u003eNo sand was encountered in Paleocene. The\r\nwell penetrated 88 m of Danian chalk (Ekofisk Formation) and 380 m Late\r\nCretaceous chalk (Tor Formation) before marls of the Rødby Formation were\r\nencountered at 3264 m. Well logs indicated that all target formations were\r\nwater wet. Shows were reported as follows: \u003c/p\u003e\r\n\r\n\u003cp\u003eMiocene (1600 m to1722 m): white bright\r\nyellow amber fluorescence giving a fast yellow white slow cut. Associated with\r\na gas peak on the chromatograph analysis at the top. Patchy fluorescence was\r\nrecorded down section. Oligocene (1829 m): bleeding gas from limestone. (2353\r\nm): pale yellow fluorescence, slow cut, with acid only. Eocene (2464 m to 2718\r\nm): patchy shows, heavy brown oil stain, very dull amber to fast yellow\r\nfluorescence, occasional fast bright yellow cut, dark brown cut colour. The\r\nShetland Group (2796 m to 3264 m): background gas only, maximum of 1.8% C1,\r\ntrace C2-C4 at 3254 m. Fair oil stain, fair to good fluorescence and cut. \u003c/p\u003e\r\n\r\n\u003cp\u003eNo conventional core was cut and no fluid\r\nsample taken. The well was permanently abandoned on 23 May 1974 as a well with\r\noil shows.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was performed\u003c/p\u003e\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"271","properties":{"OBJECTID":271,"wlbNpdidWellbore":276,"wlbName":"2/8-6","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 2/8-6 was drilled to test the chalk\r\napproximately on the crest of the Valhall structure in the southern North Sea. The\r\nValhall structure was mapped as a large northwest-southeast trending anticline\r\nat the Tertiary level covering approximately 65 km2 with a vertical relief of\r\nca 490 m. The crestal portion of the Valhall structure, ca 26 km2 in area, was\r\nblanketed by a low velocity "bright spot" zone in the overlying\r\nTertiary (Miocene). Such "bright spot" had been observed also over the\r\nHod discovery, the Ekofisk and the Eldfisk. The 2/8-6 and 2/11-2 wells had confirmed\r\nthat these "bright spot" anomalies were caused by oil and gas present\r\nin the younger Tertiary beds, creating extremely low velocities. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 2/8-6 was spudded with the\r\nsemi-submersible installation Waage Drill I on 7 April 1975 and drilled to TD\r\nat 2669 m in the Early Cretaceous Sola Formation. The well was drilled in 38\r\ndays. Of these a total of 9 days were lost due to drilling problems; 2 days\r\ncementing between the 20 and 13 3/8-inch casing to stop gas entry into the\r\nannulus, 1.5 days to repair BOP stack connector, and 5.5 days to combat gas\r\nkick and lost circulation while drilling at 2438 m. The well was drilled with\r\nseawater and hi-vis mud down to 155 m, with shale-Trol gel mud from 155 m to 1890\r\nm, and with lignosulphonate mud from 1890 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe chalk was encountered at 2463 m. Good\r\noil shows were encountered in the intervals 2465 - 2472 m and 2526 - 2551 m\r\nwith minor oil saturations occurring between the above intervals and down to\r\napproximately 2560 m resulting in a gross oil column thickness of 110 m. Log\r\nderived porosity in the oil column ranged between 27 and 43%, averaging 33 %. Cor","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"272","properties":{"OBJECTID":272,"wlbNpdidWellbore":277,"wlbName":"2/8-7","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 2/8-7 is located on the western side\r\nof the Piggvar Terrace towards the Feda Graben. The well was drilled to test\r\nthe Late Cretaceous Limestone in the Trud structure. Structurally, the Trud\r\nanomaly is a high relief, salt induced, domal feature covering approximately 19\r\nsquare kilometres. The structure was seen as highly faulted with a main fault\r\ntrending north south, with the down-thrown side to the east. The displacement\r\nalong this fault was estimated to approximately 150 m. No secondary objective\r\nwas defined.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 2/8-7 was spudded with the\r\njack-up installation Zapata Explorer on 23 July 1975 and drilled to a total\r\ndepth of 2868 m in the Late Permian salt. The well was drilled without major\r\nproblems. The well was drilled with seawater gel down to 375 m, and with a\r\nLime/Drispac/seawater mud system from 375 m to TD. The mud weight was cut and\r\nLCM pills spotted at 2619 m to cure lost circulation problems.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe Tertiary section consisted\r\npredominantly of claystone and shale. The Paleocene ash markerá (Balder\r\nFormation) was encountered at 2511 m and was found to be 12 m thick. The\r\nShetland Group chalk section (Ekofisk, Tor, and Hod Formations) was encountered\r\nat 2596 m. The Chalk section had a vertical thickness of 223 m, which compares\r\nto roughly 451 m in 2/5-4, 458 m in 2/9-1 and 280 m in 2/8-2. Oil shows were\r\nrecorded in limestone stringers below 1548 m. The target Late Crataceous\r\nsection had 12 m of oil shows from top of the Danian chalk (Ekofisk Formation),\r\nthe core from this section was boiling gas and bleeding oil from vugs and\r\nfractures. Schlumberger logs were run before the 9 5/8-inch casing was set and\r\nafter total depth was reached. Coriband log analysis estimated a water\r\nsaturation around 60% in the top Ekofisk section. A core was cut from 8538 to\r\n8554 feet (ca 2602 m to 2607 m) with 50% recovery. No fluid samples were taken.\r\nThe well was permanently abandoned on 24 August as a well","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"273","properties":{"OBJECTID":273,"wlbNpdidWellbore":278,"wlbName":"2/8-8","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 2/8-8 was drilled to appraise the\r\nValhall discovery in the southern North Sea. The well is reference well for the\r\nHod Formation.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 2/8-8 was spudded with the\r\nsemi-submersible installation Deepsea Saga on 10 November 1975 and drilled to\r\nTD at 2667 m in the Early Cretaceous Rødby Formation. While running the 13\r\n3/8-inch casing, returns (125 barrels) were lost while pumping plug. While\r\ncementing the 9 5/8-inch casing, the cement slurry was not properly displaced,\r\nand the casing was cemented back on the inside to 1022 m. Three days were lost\r\ndue to this in drilling out the cement. Otherwise the well was drilled without\r\nsignificant problems. The well was drilled with sea water and hi-vis mud down\r\nto 169 m, with sea water/gel mud from 169 m to 402 m, and with lignosulphonate/gypsum\r\nmud from 402 m to TD. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eOil shows were recorded at several levels\r\nabove the chalk reservoir: 1320 - 1329 m had fair shows on siltstones; 1390 to\r\n1426 m had poor shows in shales and limestone; 1512 to 1676 m had oil staining\r\nwith fluorescence and cut in shales; and 2050 to 2400 m had poor to fair shows\r\nin thin stringers of limestone and dolomite. Top of the chalk reservoir, Tor\r\nFormation, was encountered at 2447. It was oil bearing and had shows down to 2591\r\nm. No shows were recorded below 2591 m.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAt total of 47.7 m core was recovered in\r\n14 cores from 2450 to 2600.9 m. The overall recovery was 39 %. No wire line\r\nfluid samples were taken.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was permanently abandoned on 15\r\nMarch 1978 as an oil appraisal well.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eTesting\u003c/span\u003e\u003c/b\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"274","properties":{"OBJECTID":274,"wlbNpdidWellbore":279,"wlbName":"2/8-9","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 2/8-9 was drilled as an appraisal to\r\nhelp establish the commerciality of the southern North Sea Valhall Field, which\r\nhad earlier been discovered by 2/8-6 and confirmed by 2/8-8. The primary\r\nobjective of 2/8-9 was an evaluation of the Chalk reservoirs of Maastrichtian (Tor\r\nFormation) and pre-Maastrichtian (Hod Formation) age. The existence of\r\nhydrocarbons in the Early-Middle Miocene section creates a low velocity\r\n"bright spot" on the seismic, blanketing the crest of the Valhall\r\nstructure and causing "dimming" or total loss of the top chalk\r\nsection. The Valhall crest is therefore an area where the estimated thickness\r\nof the Tor section and the fault patterns are questionable. Only one previous\r\nwell, 2/8-4, had been drilled in the vicinity some 2.5 km to the west. Well\r\n2/8-4 was essentially a dry hole with only 1 m of Tor and tight but oil bearing\r\nHod Formation. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 2/8-9 was spudded with the\r\nsemi-submersible installation Sedco 135 G on 9 April 1976 and drilled to TD at 2703\r\nm in the Early Cretaceous Rødby Formation. The well was drilled in a total of\r\n30 days, without any major drilling problems. It was drilled with sea water and\r\nviscous mud down to 183 m, with seawater and gel from 183 m to 392 m, and with\r\nDrispac/lime/seawater mud from 392 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 2/8-9 penetrated a normal of\r\nQuarternary -Tertiary section from surface to top of the Late Cretaceous. The\r\nDanian was found to have been removed by erosion. The well found the Chalk\r\nhydrocarbon bearing at 2524 m correlating 53.3 m high and 76.8 m low to wells\r\n2/8-4 and 2/8-8, respectively. The Tor Formation was 5.5 m thick with high\r\nreservoir quality; porosity of up to 48% and a water saturation close to zero. The\r\nHo","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"275","properties":{"OBJECTID":275,"wlbNpdidWellbore":280,"wlbName":"2/8-10","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 2/8-10 was drilled as a field\r\ndelineation well intended to help establish the commerciality of the Valhall\r\nField, which was discovered by well 2/8-6 and confirmed by wells 2/8-8 and\r\n2/8-9. The main purpose of 2/8-10 was to evaluate the Tor and Upper Hod\r\nreservoirs on the south eastern flank of the Valhall structure.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 2/8-10 was spudded with\r\nthe semi-submersible installation Sedco 135 G on 30 June 1976 and drilled to TD\r\nat 2682 m in the Early Cretaceous Rødby Formation. The well was drilled with\r\nseawater and bentonite down to 375 m, and with seawater/lime/Drispac mud from\r\n375 m to TD. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe objective reservoirs, developed in\r\nchalk of the Tor and Hod Formations, were encountered at depths of 2476.5 m and\r\n2516 m respectively. A gross pay interval of 77 m was encountered. The Tor\r\nFormation was approximately 38 m thick with an oil saturation of 95% and was\r\ntested at rates of up to 1000 Sm3/day. The upper Hod reservoir, approximately\r\n38 m thick, was found to be hydrocarbon bearing, although oil saturations were\r\nlow, averaging 25% and the reservoir was tested at up to 67 Sm3/day. As\r\nanticipated, the lower Hod reservoir was wet. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eOnly insignificant, although fairly\r\nconsistent, oil shows were encountered in the Hordaland and Rogaland Groups.\r\nExcellent shows were recorded in the Tor Formation. The quality of the shows\r\ndecreased gradually through the upper part of the Hod Formation and only minor\r\noil shows were encountered below 2570 m.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eFour conventional cores were cut in the\r\ninterval 2477.1 m to 2508.5 m with an overall recovery of 70%. No wire line\r\nfluid samples were taken.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp c","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"276","properties":{"OBJECTID":276,"wlbNpdidWellbore":281,"wlbName":"7/12-6","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 7/12-6 was drilled as an appraisal\r\nwell on the Ula Field in the southern North Sea. The objective was to determine\r\nsand distribution in northern part of the Ula field, and production and\r\ninjection properties of reservoir and aquifer.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 7/12-6 was spudded with\r\nthe semi-submersible installation Sedco 707 on 10 April 1981 and drilled to TD\r\nat 3700 m in the Triassic Skagerrak Formation. Some hole problems and excessive\r\ncavings due to underbalanced drilling occurred in the 12 1/4" section\r\nbetween 2633 and 3353 m, otherwise the well was drilled without significant\r\ntechnical problems or delay. The well was drilled with gel/seawater and fluid\r\nloss additives down to 480 m and with gypsum/lignosulphonate and fluid loss\r\nadditives from 480 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe Ula Formation sandstones were penetrated\r\nat 3406 m. The sandstones were 115 m thick, very fine to fine grained with\r\nporosities from 10 to 25% and permabilities from 1 to 2000 mD. The reservoir\r\nwas oil bearing throughout, no OWC was established. An unexpected Triassic\r\nreservoir of good quality was found below the Ula Formation. The well drilled\r\n179 m into it without reaching the OWC. The reservoir consisted of various\r\ntypes of micaceous sandstones with porosities from 4 to 23% and permabilities\r\nfrom 0.03 to 2600 mD. The first hydrocarbon indication was recorded as a weak\r\noil show at 2440 in siltstone. Further shows were recorded in the Late\r\nCretaceous between 3010 m and 3060 m, however the logs did not indicate any\r\nsignificant mobile hydrocarbon. Hydrocarbon shows were recorded throughout the\r\nUpper Jurassic Ula Formation between 3407 m and 3521 m. Patchy shows were\r\nrecorded in the Triassic interval between 3521 m and TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"277","properties":{"OBJECTID":277,"wlbNpdidWellbore":282,"wlbName":"2/9-1","wlbHistory":"\u003cp\u003eWell 2/9-1 was the first exploratory well\r\nto be drilled in Block 2/9 of the Norwegian concession area of the North Sea.\r\nThis block occupies a position in the central part of the North Sea, a little\r\nto the southeast of the Eldfisk - Ekofisk - Tor Oilfields area. It is thus\r\nlocated over the deepest part of the North Sea Tertiary Basin. The well was\r\nplanned to be drilled on the border between block 2/8 and block 2/9, the final\r\nwell position is actually in block 2/8.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 2/9-1 was spudded with the\r\njack-up installation Zapata Explorer on 3 November 1972 and drilled to TD at\r\n3551 m in the Late Cretaceous Hod Formation. The well was drilled with a\r\nseawater and bentonite down to 387 m and with a polymer mud system with 1 % û 4\r\n% oil from 387 m to TD. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe Rogaland Group was encountered at\r\n2962.7 m and consisted of the Balder, Sele, Lista, and Maureen formations.\r\nInterval 3065.7 m to Top Ekofisk Formation at 3092 m consisted of marl (Maureen\r\nFormation). From this point to TD the well drilled Late Cretaceous chalk\r\n(Ekofisk, Tor, and Hod formations). The best porosity in this sequence, based\r\non log analyses, was seen in the interval 3209.5 m to 3261 m in the Tor\r\nFormation was. However, no shows were recorded in the well. No fluid samples\r\nwere taken and no conventional core was cut. A wire line core slice was\r\nretrieved from 3499.4 m to 3500.3 m in the Hod Formation. The slice is\r\ndescribed in a report by Robertson Research. The well was permanently abandoned\r\nas dry on 7 December 1972.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was performed\u003c/p\u003e\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"278","properties":{"OBJECTID":278,"wlbNpdidWellbore":283,"wlbName":"2/9-2","wlbHistory":"\r\n\r\n\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 2/9-2is located on the Piggvar\r\nTerrace in the southern North Sea. The primary objective was to test a broad\r\nstructural closure where Jurassic Sands were postulated to be present along the\r\nnarrow intermediate zone between the Mandal High to the east and the Central\r\nGraben to the west.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 2/9-2 was spudded with the\r\nsemi-submersible installation Dyvi Alpha on 7 July 1979 and drilled to TD at 4367\r\nm in the Early Permian Rotliegend Group. The well was drilled without\r\nsignificant problems. However, four days were spent on retrieving the wear\r\nbushing prior to running the 13 3/8-inch casing. The well was drilled to 1513\r\nmeters using seawater, spotting high viscous gel pills occasionally while\r\ndrilling and upon completion of each hole interval. A weighted Gypsum-polymer\r\nmud was used below this depth to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe Late Jurassic was encountered at 3653\r\nm, 16 m low to prognosis, confirming the structural interpretation. The Late\r\nJurassic section (3653-4293 m) consisted of 640 meters of predominantly black\r\nshale with no sands and was age-dated Middle Kimmeridgian-Portlandian. No\r\nJurassic rocks older than Middle Kimmeridgian were found. From 4290-4325 m, the\r\nsection was silty and sandy but impermeable. From 4325 m to TD lithology was\r\ninterpreted to be weathered volcanics of possibly Permian age, with caved\r\nKimmeridgian shales. Stratigraphic and petrophysical data pertinent to further\r\nevaluation of the Jurassic zone was secured through the acquisition of one conventional\r\ncore and an almost complete set of open hole logs. Poor to very poor shows were\r\nseen in the intervals 4135 - 4155 m and 4160 - 4182.5 m in the Late Jurassic.\r\nThey were describ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"279","properties":{"OBJECTID":279,"wlbNpdidWellbore":284,"wlbName":"2/10-1 S","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThe 2/10-1 S "South East Eel"\r\nwell is located in the Grensen Nose, close to the southern tip of the Norwegian\r\nsector. It was drilled in the Tertiary basin of the North Sea approximately 20\r\nkm south of the Embla discovery. The primary objective horizons were the Early\r\nCretaceous - Late Jurassic clastic sediments and the Danian - Late Cretaceous\r\nlimestones. Seismic data were interpreted as wedging out of the Early\r\nCretaceous - Late Jurassic sediments up-dip to the west of the well location.\r\nThese sediments produced oil in the Phillips 2/7-3 and 2/7-9 wells while Late\r\nJurassic turbidite sands were present in the Eldfisk 2/7-1 well. In addition a\r\nsmall Danian/Late Cretaceous structure was defined on a seismic. The 2/7-2 well\r\na few miles to the north in a similar geological situation produced 345 BOPD\r\nfrom the Danian. Secondary objectives were Tertiary and possible Rotliegendes\r\nsandstones.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eExploration well 2/10-1 S was spudded\r\nwith the semi-submersible installation Ocean Viking on 16 September 1975 and\r\ndrilled deviated to TD at 4609 m (4267 m TVD RKB) in rocks of possibly\r\nCarboniferous age. While drilling the 8 1/2" section at 4028 m the weather\r\ndeteriorated. The drill string was hung off before the rig started to drift,\r\nand had to be towed to Stavanger. Winds were reported up to 30 m/s and waves up\r\nto 22 m. Altogether 34 days were lost before the rig again was on location and\r\ncould continue drilling. The well was drilled with sea water and gel down to\r\n442 m and with PAC/sea water with 4% oil from 442 m to TD. \u003c/p\u003e\r\n\r\n\u003cp\u003eNo oil shows were encountered during the\r\ndrilling, however, a gas kick was noted when drilling into the top of the\r\nRotliegendes sandstone section. No testing was carried out due to engineering\r\ndifficulties although three drill stem tests in the Permian were planned. The\r\nwell was drilled as per progress down to the base of the Cretaceous sediments.\r\nNo clastics were developed in the Te","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"280","properties":{"OBJECTID":280,"wlbNpdidWellbore":285,"wlbName":"2/11-2","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 2/11-2 was drilled on the Hod\r\nprospect on the Skrubbe Fault between the Lindesnes Ridge and the Ål Basin in\r\nthe southern North Sea. The "Hod" anticline is a satellite or\r\nsubsidiary feature immediately to the southwest of the large Valhall structure.\r\nThe primary objective was the Danian/Late Cretaceous chalk section, the\r\nproductive horizon in surrounding fields. Paleocene sand/siltstones would be\r\nsecondary objectives, if encountered. These had shows in well 2/11-1, located\r\n6.4 km north.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 2/11-2 was spudded with the\r\nsemi-submersible installation Zapata Explorer on 6 November 1974 and drilled to\r\nTD at 2806 m in the Early Cretaceous Rødby Formation. It was drilled in 37 days\r\nwithout major problems, although 10 days were lost due to waiting on water,\r\ncombating lost circulation after an attempt to kill a gas kick, and waiting on\r\na new BOP stack after a leak was found on the old equipment. The well was drilled\r\nwith seawater and Milben saltgel mud down to 145 m, with seawater, pre-hydrated\r\nMilben, Flosal mud from 145 m to 383 m, with Drispac/Flosal mud from 385 m to\r\n1295 m, with Shale Trol until gumbo, converting to a Unical/seawater mud from\r\n1295 m to 2660 m, and with a Unical/seawater mud from 2660 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eHigh gas readings were recorded from\r\napproximately 1415 m to 1675 m. Oil shows (dull yellow fluorescence and poor -\r\nfair cut) and free oil in the mud was also noted during the drilling of the\r\nabove interval. Oil bearing Santonian - Coniacian chalk (Hod Formation) was\r\nencountered at 2640.5. The section had 51.5 m net pay with estimated average\r\nporosity of 27.7 percent and an average water saturation of 40.3 percent. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eA core was t","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"281","properties":{"OBJECTID":281,"wlbNpdidWellbore":286,"wlbName":"2/11-3","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 2/11-3 is located 2.5 km due east\r\nfrom 2/11-2 and 6.5 km south-southeast from the Valhall well 2/11-1. The\r\nprimary objective of well 2/11-3 was the Late Cretaceous chalk section on the\r\nwestern flank of the East Lobe of the Hod structure. The West Lobe was found to\r\nbe oil bearing by 2/11-2 in 1974. Seismic indicated an expansion of the chalk\r\nsection compared to 2/11-2 and that the graben feature found on Valhall\r\nextended south-eastward over the East Hod and therefore the possibility for the\r\nhigh reservoir quality Maestrichtian rock to be present in this area.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 2/11-3 was spudded with the jacket 4\r\nlegs installation Dyvi Beta on 10 October 1977 and drilled to TD at 3052 m in\r\nthe Early Cretaceous Rødby Formation. The well was drilled in a total of 47\r\ndays without any major drilling problems. However, 3 days were spent waiting\r\nfor the correct Cameron BOP Adaptor Spool.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 2/11-3 proved the Hod complex to\r\nconsist of two individual structures. A domal West Hod structure has a\r\nseismically defined closure area of 7.5 square km. East Hod, where 2/11-3 was\r\nlocated, is a northwest-southeast trending anticline covering approximately 6\r\nsquare km. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well penetrated a normal sequence of\r\nQuarternary-Tertiary section from the surface to the top of the Late Cretaceous\r\nat 2774.5 m. This interval typically consists of predominantly clay and shale\r\nwith thin stringers of limestone and dolomite scattered throughout. The basal\r\nTertiary unit is marked by the occurrence of the Paleocene Ash marker that\r\ndisplays the characteristic metallic blue grey-violet colour of the volcanic\r\ntuff. This correlative unit was encountered at 2714.5 m and is 18 meters thick.\r\nThe cha","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"282","properties":{"OBJECTID":282,"wlbNpdidWellbore":287,"wlbName":"2/11-3 A","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe Hod complex was proved to consist of\r\ntwo individual structures by well 2/11-3, which was drilled about 2.5 km due\r\neast of 2/11-2. Seismically, the Hod structural complex is difficult to map due\r\nto shallow gas in the Tertiary, mainly over the western part of the structure,\r\nwhich complicates the time to depth conversion. As it turned out, the chalk in 2/11-2\r\nwas drilled close to the limit of structural closure of the East Structure and\r\nwas therefore dry with shows only. Well 2/11-3 A was a sidetrack from well\r\n2/11-3 to test Late Cretaceous chalk in a graben feature indicated by seismic\r\nin the crestal regional of the East Hod structure. A graben, if present, would\r\nhave possibilities for preservation of younger Maastrichtian rock which in\r\ngeneral is of high reservoir quality with high porosity and often very high oil\r\nsaturation. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 2/11-3A was sidetracked from just\r\nbelow the 13 3/8-inch casing shoe on 3 December 197 7 and drilled to TD at a\r\ntotal measured depth of 3400 m (2857 m TVD) in the Late Cretaceous Hod\r\nFormation. The pipe stuck at TD prior to logging and deviation survey. After\r\nworking on the stuck pipe the string was disconnected at 3189 m and the well\r\nwas kicked-off on the low side in order to complete logging and testing of the\r\npay-zone discovered before the pipe got stuck. This technical sidetrack was\r\ndrilled to 3333 m (2812 m TVD). \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eTop Chalk was encountered in the\r\nsidetrack at 3189.5 meters (2713 meters TVD). The uppermost 5 m belonged to the\r\nEkofisk Formation. Then followed 58.5 m of Tor Formation, 13 m of tight Middle\r\nHod Formation, and 70 m of Lower Hod. The Chalk was found oil bearing from top\r\nChalk to TD in the sidetrack, with exception of 8 m in Middle Hod. Shows on\r\ncuttings wer","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"283","properties":{"OBJECTID":283,"wlbNpdidWellbore":288,"wlbName":"2/11-5","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 2/11-5 was drilled on the western\r\nlobe of the Hod Field to test the Late Cretaceous Chalk section. The well was\r\nlocated 1.8 km SSE of 2/11-2 which tested oil from a very thin Chalk section of\r\nthe Lower Hod Formation. Structural interpretations were made showing a NW-SE\r\ntrending graben traversing the West Hod lobe. Based on a model from East Hod,\r\nit was expected that the porous Tor Formation should be preserved below the\r\nunconformity within this structure.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 2/11-5 was spudded with the\r\nsemi-submersible installation Dyvi Alpha on 18 May 1979 and drilled to TD at 2945\r\nm in the Early Cretaceous Rødby Formation. No significant problem was\r\nencountered in the operations, however six days were spent repairing the BOP\r\nstack before it could be run and two days were spent while mixing oil-based\r\nmud. The well was drilled with seawater, bentonite and CMC EHV down to 1285 m,\r\nwith gyp/CMC mud from 1285 m to 2320 m, with lignosulphonate mud from 2320 m to\r\n2765 m, and with oil based "Oilfaze" mud from 2765 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe Paleocene Ash Marker (Balder\r\nFormation) was encountered at 2715 m; 105 m low to prognosis. The top of the\r\nChalk Group, Ekofisk Formation was encountered at 2822 m; 117 m low to\r\nprognosis. In total, the Chalk section was found to be 98 m thick, whereas 300\r\nm was predicted. These discrepancies reflect the effects of the shallow gas in\r\nthe area on the seismic data. The velocity corrections which were applied to\r\nthe seismic were too large. As a consequence, the Chalk Group within the Graben\r\nwas found below the oil-water contact of the area and no moveable hydrocarbons\r\nwere encountered. Frequent oil shows were reported however, starting in the\r\nupper part of the Hordaland Group: \u00A0\u00A0\u00A0\u00A0\u00A0\u00A0\u00A0\u00A0\u00A0\u00A0\u00A0\u00A0\u00A0","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"284","properties":{"OBJECTID":284,"wlbNpdidWellbore":289,"wlbName":"2/11-6 S","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 2/11-6 S was drilled on the\r\nLindesnes Ridge in the southern North Sea. The objective was to appraise the\r\nHod discovery made by well 2/11-2 in 1974 (Hod West) and appraisal well 2/11-3\r\nin 1977 (Hod East). The Hod structure is oil-bearing in Late Cretaceous chalks,\r\nthe Hod and Tor formations. Well 2/11-6 S targeted the Hod East structure.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 2/11-6 S was the first\r\nwell to be drilled on a subsea template which was laid by the semi-submersible\r\ninstallation Sedco 703. It was then drilled with Sedco 703 through slot number\r\nW7 of the twelve slot templates, to TD at 3970 m (2905 m TVD) where the pipe got\r\nstuck. The pipe was shot off with top of the fish at 3669 m and a technical\r\nsidetrack 2/11-6 ST1 was kicked off from 3626 m. The sidetrack was drilled to\r\nthe final TD at 4076 m (2980 m TVD). The initial well bore was drilled with\r\nseawater and hi-vis sweeps down to 1460 m, with Vertoil oil based mud from 1460\r\nm to 3601 m, and with Oilfaze oil based mud from 3601 m to 3970 m. The 2/11-6\r\nST1 sidetrack was drilled with Vertoil oil based mud from kick-off to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 2/11-6 drilled a nearly complete\r\nTertiary section and penetrated top chalk at 3690 m (2732 m TVD). The sidetrack\r\npenetrated top of the chalk group at 3685 m (2729 m) with a slightly lower\r\nangle (50 deg) than in the initial well bore (55 deg). The chalk stratigraphy\r\nin the two well bores was very similar apart from the angle/depth shift. The\r\nwell tested oil in the Tor / upper Hod formations and in the lower Hod\r\nFormation. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eSeven conventional cores were cut from\r\n3693 to 3741 m in the initial well bore before side tracking. The cores were\r\ncut in the Late Cretaceous Chalk. The total recove","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"285","properties":{"OBJECTID":285,"wlbNpdidWellbore":290,"wlbName":"3/5-1","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eExploration well 3/5-1 is located near\r\nthe Coffee Soil Fault Complex on the northeast border of the Søgne Basin. The\r\nmain objective of the well was to test the hydrocarbon potential of\r\nRotliegendes sands on the crest of a tilted fault block, which was thought to\r\nmark the local eastern edge of the Central Graben of the North Sea. A secondary\r\ntarget was the basal Zechstein, where it was hoped that any dolomites present\r\nmight have developed the secondary porosity exhibited in the Auk and Argyll\r\nFields lying on the Western side of the Central Graben. There was no mappable\r\nclosure at any post Zechstein horizon.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 3/5-1 was spudded with the\r\nsemi-submersible installation Odin Drill on 3 May 1978 and drilled to TD at\r\n3426m in basal conglomerates of the Permian Rotliegendes Group. While drilling\r\nat 2561 m the string twisted of at the jars, costing some six days lost time. A\r\nsalt-water flow occurred while drilling at 2918 m, but was controlled by\r\nincreasing the mud weight from 11.3 to 12.4 lb/gal. During abandonment 2.3 days\r\nwere spent cutting and retrieveing of the well head. The well was drilled with\r\nseawater and hi-vis slurry down to 466.3 m and with lime/Drispac mud from 466.3\r\nm to ca 2228 m from where it was gradually displaced to a Spersene/Resinex mud\r\nsystem. This mud was in turn displaced to a salt saturated mud from ca 3058 m\r\nafter it became clear that massive salt was being drilled. The salt saturated\r\nmud was used to drill the rest of the well to TD. \u003c/p\u003e\r\n\r\n\u003cp\u003eSchlumberger's CPI log showed almost 23 m\r\nof reservoir quality sands in the Late Jurassic (average log porosity 24 %),\r\nand almost 259 m in the Rotliegendes (average log porosity 23 %). A thick salt\r\nsection covered the Zechstein carbonates. It is probable that the salt-water\r\nflow at 2918 m came not from this salt but from the overlying Jurassic\r\nsandstones. Shows were recorded while drilling the Late Jurassic Kimmeridgian\r\n"Hot" Shale (M","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"286","properties":{"OBJECTID":286,"wlbNpdidWellbore":291,"wlbName":"3/5-2","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eExploration well 3/5-2 is located in the\r\neastern part of the Søgne Basin. The main objective was to test the hydrocarbon\r\npotential of northeasterly dipping Jurassic sands, which appeared to be\r\ntruncated up dip by erosion at a Late Kimmerian unconformity. The exact age of\r\nthe beds above and below the unconformity could not be predicted with certainty\r\nwith the seismic evidence available. There was no capable closure at any post\r\nunconformity horizon higher than that mapped as Late Kimmerian unconformity\r\njust above a possible Jurassic Sand.\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 3/5-2 is Reference well for the\r\nMiddle to Late Jurassic Haugesund Formation\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 3/5-2 was spudded with the\r\nsemi-submersible installation Odin Drill on 29 June 1978 and drilled to TD at\r\n3826 m in the Triassic Skagerrak Formation. The well was drilled without\r\nsignificant problems. After drilling 164 m of 36" hole the pipe was stuck,\r\nbut after spotting two 60 Bbl LCM pills followed by an 85 Bbl pill of Pipe Lax\r\nthe string pulled free without significant lost time. Drilling went on through\r\nthe 26" section to 462 m using viscous gel mud. From 426 m to TD the well\r\nwas drilled using a Drispac/Spersene mud system, adding Resinex from ca 3080 m.\u003c/p\u003e\r\n\r\n\u003cp\u003eReservoir potential was encountered in\r\nthe Late Cretaceous Chalk (Maastrichtian 2708.5 m to 2726.5 m) and in Late\r\nJurassic (3174 m to 3185 m) and Triassic (3575 m to 3823.5 m) sandstones.\r\nGeochemical analyses proved oil prone shale, marginally mature (%Ro = 0.6 û\r\n0.7), in the Late Jurassic Kimmeridge Clay with TOC measured up to2.1 %. Also\r\nthe Middle Jurassic Haldager Formation contained shales with potential for gas\r\nand possibly some oil. Vitrinite reflectance in one sample from this Formation\r\nwas %Ro = 0.85. Small quantities of C1 to C4 were recorded in the Late Jurassic\r\nKimmeridge Clay Formation (3143 m to 3163 m) and in even smaller amounts in\r\nshales at the top of the Middle Jurassic (3331 m to 3359 m","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"287","properties":{"OBJECTID":287,"wlbNpdidWellbore":292,"wlbName":"3/7-1","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 3/7-1 was drilled in the Søgne Basin\r\nin the North Sea, about 1400 m north of the border to Danish waters. The well\r\nlocation is near the top of a large anticline whose axis trends northwest with\r\na 200 km2 closure at the pre-Zechstein horizon. The structure was considered as\r\na north-western extension of the Fynn Falster High. The expected reservoirs\r\nwere Danian and Maastrichtian chalky limestone, Jurassic sandstone, Rotliegend\r\nsandstone, and Carboniferous or Devonian sandstone. It was supposed that all or\r\nnone of these reservoirs could be encountered. Basement could be found at\r\ndifferent depths, owing to the difficulties in identifying main seismic\r\nhorizons below the top of the chalky limestone.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 3/7-1 was spudded with the jack-up\r\ninstallation Ocean Tide on 1 August 1973 and drilled to TD at 3227 m, 9 m into\r\nbasement rock. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe Paleocene and Maastrichtian horizons\r\nwere encountered at 2690 m and 2852 m respectively, which was 41m and 28 m low\r\nto the geologic prognosis estimated depths. The basement (chloritic gneiss) was\r\nencountered directly underlying Turonian limestone.\u003c/p\u003e\r\n\r\n\u003cp\u003eOnly the middle part of the chalky Maastrichtian\r\nsection had some reservoir characteristics with inferred porosity from the BHC\r\nlog about 12% from 2852 m to 2951 m and about l8% from 2951 to 2984.5 m. The Maastrichtian\r\nreservoir was water wet based on the IES log. The underlying Turonian -\r\nCampanian limestone was very tight. No hydrocarbon shows were reported from the\r\nwell other than traces of dry gas. \u003c/p\u003e\r\n\r\n\u003cp\u003eOne core was cut in basement at TD from\r\n3221 - 3227 m. No fluid samples were obtained.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 13\r\nSeptember 1973 as a dry well.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was performed.\u003c/p\u003e\r\n\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"288","properties":{"OBJECTID":288,"wlbNpdidWellbore":293,"wlbName":"3/7-3","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 3/7-3 was drilled on a salt diapir in\r\nthe southern part of the Søgne Basin in the North Sea. The primary target of\r\nthe well was Danian/Late Cretaceous chalk, which had been found hydrocarbon\r\nbearing in the Ekofisk area and in the Danish well Lulu 1. Secondary target was\r\nMiddle Jurassic sandstones, which had been found hydrocarbon bearing in well\r\n2/6-2. The TD was planned below the top of the Zechstein salt in order to test\r\npossible Early Jurassic and/or Triassic sandstones.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 3/7-3 was spudded with the\r\nsemi-submersible installation Dyvi Alpha on 21 June 1981and drilled to TD at 3540\r\nm in the Late Permian Zechstein salt. At 1968 m, in the Late Eocene, a drilling\r\nbreak was experienced and the well started to flow. The flow was killed with a\r\nmud weight of 1.55 g/cc. After setting the 13 3/8" casing shoe at 1961 m,\r\nthe well was controlled after gains and losses with a mud weight of 1.58 g/cc. No\r\nother problems were encountered while drilling. The well was drilled with\r\nseawater and bentonite down 666 m, with seawater/SST 202/FCL mud from 666 m to\r\n1970 m, and with seawater/FCL/LC mud from 1970 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eTertiary sands with a thickness of 37.5 m\r\nwere encountered in the Paleocene. They were water bearing. The chalk, which\r\nwas the main target, was relatively tight and water bearing. At 3325 m a 107\r\nmeter thick water bearing sandstone of Latest Jurassic - Earliest Cretaceous\r\nage (Kimmeridgian - Berriasian) was encountered. Below this sandstone Kimmeridgian\r\nshales rested directly on the Zechstein anhydrite. No shows were noted in the\r\nwell.\u003c/p\u003e\r\n\r\n\u003cp\u003eThree cores were cut; one from 2830 to\r\n2848 m in the Danian chalk (60% recovery) and two in the Beriasian Sandstones\r\nfrom 3337.5 to 3339 m (67% recovery) and from 3339 to 3348 m (100% recovery). No\r\nwire line fluid samples were taken.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 31\r\nAugust 1981as a dry well.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eN","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"289","properties":{"OBJECTID":289,"wlbNpdidWellbore":294,"wlbName":"7/8-2","wlbHistory":"\u003cp\u003eThe 7/8-2 (Cero) well was drilled on a\r\ndomal structure approximately 6 km long by 6 km wide, situated on the Jæren\r\nHigh in the North Sea. It was estimated that at Paleocene depth there would be close\r\nto 40 square km of closure with 140 m of vertical relief and at Early\r\nCretaceous depth 27 square km of closure with 150 m of vertical relief. The\r\nprincipal objective horizons were Paleocene, Jurassic and Triassic sands with\r\nthe Danian-Cretaceous limestone as a possible secondary objective. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 7/8-2 was spudded with the\r\nsemi-submersible installation Ocean Viking on 24 July 1973 and drilled to TD at 3006 m in anhydrite of the Zechstein Group. No significant problems are\r\nreported from the operations. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe well had no hydrocarbons or shows of\r\nhydrocarbons. In the Paleocene no sand beds were developed, although sand was\r\npresent as a loose, unconsolidated constituent in most of the clays and shales.\r\nThe Danian and Late Cretaceous limestones were tight. The Late Cretaceous\r\nsection was 150 m thinner than anticipated due to erosion of the Coniacian to\r\nCenomanian formations at the base. The Jurassic succession was encountered at\r\n2808 m and top Triassic at 2883 m. Two Triassic sands were encountered at 2911\r\n- 2937 m and at 2972 - 2996 m. The Triassic section was thinner than expected,\r\nbeing truncated at 2996 by the Permian Zechstein Group.\u003c/p\u003e\r\n\r\n\u003cp\u003eNo cores were cut and no wire line fluid\r\nsamples were taken in the well.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 29 August 1973 as a dry well.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was performed.\u003c/p\u003e\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"290","properties":{"OBJECTID":290,"wlbNpdidWellbore":295,"wlbName":"7/12-2","wlbHistory":"\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 7/12-2 was drilled on a salt induced\r\nstructure on the east side of the Cod Terrace in the North Sea. The primary\r\nobjective was to evaluate potential Upper Jurassic and Triassic reservoirs\u00A0 \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well is Type well for the Ula Formation\r\nand Reference well for the Farsund Formation.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 7/12-2 was spudded with the\r\nsemi-submersible installation Norskald on 4 July 1976 and drilled to TD at 3676\r\nm in the Early Jurassic Gassum Formation. The well was drilled with\r\nseawater/gel down to 158.5 m and with seawater/lime Drispac mud from 158.5 m to\r\nTD down to 495 m and with a lime/Drispac mud from 495 m to TD. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 7/12-2 penetrated a major Late\r\nJurassic reservoir (Ula Formation) and was terminated within a hydrocarbon\r\nbearing sequence of poor quality sands and interbedded shales in the Gassum\r\nFormation. Core analysis and log interpretation indicate an Ula Formation\r\nsandstone reservoir of 128 m net thickness (154 m gross) with porosities\r\nranging from 14 to 28%, permeabilities from a few millidarcy to over two darcy\r\nand water saturations from 5 to over 50%. The Ula Formation was oil bearing\r\nfrom top to base at 3532 m in an oil down-to setting. The Gassum Formation\r\nsandstones have a porosity between 11 and 19%, average permeability of 1 md and\r\nwater saturation generally in excess of 70%.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eEleven cores were cut in the well. Cores\r\none to ten were cut in succession from 3385.75 m (3380.95 m logger's depth) to\r\n3476.9 m (3470.9 m logger's depth) in the Ula Formation. The overall core\r\nrecovery for this section was 97.3%. Core no 11 was cut in the Early Jurassic from\r\n3634.2 to 3652.3 m with 100% recovery. The core-l","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"291","properties":{"OBJECTID":291,"wlbNpdidWellbore":296,"wlbName":"7/12-3","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 7/12-3 was drilled as an appraisal\r\nwell on the western flank of the 7/12-2 Ula Discovery in the North Sea. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 7/12-3 was spudded with\r\nthe semi-submersible installation Norskald on 5 April 1977 and drilled to TD at\r\n3710 m in Late Jurassic sediments. The drilling, coring and logging of the well\r\nwere of a routine nature. Plugging of the flow lines and screens by hydrating\r\nclays while drilling the 17-1/2" hole caused delays and the loss of considerable\r\nquantities of mud. Rates of penetration were less than anticipated in the Lower\r\nCretaceous and Upper Jurassic mudstones/ shales. Ninety-four hours were lost\r\nthrough weather delays during the course of the well. The well was drilled with\r\nfresh water and gel down to 471 m and with Lime/Drispac mud from 471 m to TD. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eCore, log and R.F.T. analyses proved the\r\nwell to have penetrated the Jurassic reservoir discovered in well 7/12-2\r\nbeneath the oil water contact.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eOne core was cut in the Jurassic section,\r\nfrom 3612.2 to 3628.6 m. An RFT water sample was taken at 3683 m\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was plugged back for sidetracking\r\non 3 June as a dry well.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eTesting\u003c/span\u003e\u003c/b\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo drill stem test was performed. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"292","properties":{"OBJECTID":292,"wlbNpdidWellbore":297,"wlbName":"7/12-3 A","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 7/12-3 A is a geological sidetrack\r\nto 7/12-3 on the western flank of the 7/12-2 Ula discovery in the North Sea. The\r\nprimary objective was to establish the oil-water level in the Ula structure. \u00A0\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well is type well for the Mandal\r\nFormation.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eOn 4 June 1977 appraisal well 7/12-3 A was\r\nkicked off from below the 13 3/8” casing shoe in well 7/12-3 at a depth of 1720.\r\nThe semi-submersible installation Norskald drilled the well to TD at 4191 m\r\n(4011 m TVD) in the Permian Zechstein Group. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 7/12-3A penetrated the reservoir at\r\n3638.5 (3506.8 m TVD). The cores showed oil staining, cut and fluorescence.\r\nWire line logs and testing showed this to be immovable oil, and indicated an\r\noil water transition zone to a depth of 3693.5. (3555.3 m TVD). One hundred and\r\neighty-nine meters of Ula Formation reservoir were encountered representing a\r\ntrue thickness of 168.9 m, and a net to gross ratio of 0.83 assuming a 10%\r\nporosity cut off on the computer-processed log.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eSeven full hole cores were cut from 3642.0\r\nto 3730.0 m. RFT fluid samples were taken at 3675.5 m (salt water and mud\r\nfiltrate) and 3688.5 m (salt water with traces of gas and oil/oil-water\r\nemulsion).\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was permanently abandoned on 6\r\nSeptember 1977 as a dry well with shows.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eTesting\u003c/span\u003e\u003c/b\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eDST 1 tested the interval 3771.0 to\r\n3715.5m. The test flowed 192 m3 saline formation water /day through a 32/64\r\nchoke. The DST temperature was 146.7 °C.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyTe","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"293","properties":{"OBJECTID":293,"wlbNpdidWellbore":298,"wlbName":"7/12-4","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 7/12-4 was drilled as an appraisal\r\nwell on the Ula Field in the North Sea. The main objective was to evaluate the\r\nextent and hydrocarbon potential of the Late Jurassic sands in the south\r\neastern flank of the structure. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 7/12-4 was spudded with\r\nthe semi-submersible installation Nordskald on 11 September 1977 and drilled to\r\nTD at 3623 m in Early Jurassic sediments of the Bryne Formation. Operations\r\nproceeded without significant problem. The well was drilled with fresh\r\nwater/gel down to 498 m and with lime/Drispac mud from 498 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe target reservoir Ula Formation was\r\nencountered at 3445 m, while the underlying Bryne Formation came in at 3529 m. Net\r\nsand in the reservoir was 73 m with porosity from 10 to 23%, permeability from\r\na few millidarcy to 1750 millidarcy, and water saturation from 5 to over 60%. The\r\nreservoir was oil-bearing with a possible OWC at 3551 m in the Bryne Formation based\r\non disappearance of oil shows; however, drill stem tests showed that the producible\r\ncontact between oil and water was between 3530 and 3536 m.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eSeven cores were cut from near top Ula\r\nFormation at 3447.5 m to 3556.7 m in the Bryne Formation. The recovery was 100%\r\nin core one to six and 96% in core seven. RFT fluid samples were taken at 3458\r\nm (oil, emulsion and water), 3467 m (emulsion) and at 3528 m (water)\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was suspended on 12 December\r\n1977 for possible use as a producer at a later stage. It is classified as an oil\r\nappraisal well.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eTesting\u003c/span\u003e\u003c/b\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eProduction test","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"294","properties":{"OBJECTID":294,"wlbNpdidWellbore":299,"wlbName":"7/12-5","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 7/12-5 was drilled ca 4 km northwest\r\nof the Ula Field in the North Sea. The objective was to test the hydrocarbon\r\npotential in Late Jurassic Sandstones. Secondary objectives were Early Jurassic\r\nand Triassic sandstones.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 7/12-5 was spudded with the\r\nsemi-submersible installation Borgsten Dolphin 6 February 1981 and drilled to\r\nTD at 4440 m in the Late Permian Zechstein Group. There were some problems with\r\ndrilling the section from 2851 to 3741 m due to junk in hole, otherwise\r\noperations proceeded without significant problems. The well was drilled with sea\r\nwater and hi-vis pills and gel down to 467 m and with\r\ngypsum/lignosulphonate/CMC mud from 467 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe Mandal Formation was penetrated at 3731\r\nm, while the Farsund Formation was penetrated at 3763 m. The Ula Formation was\r\npenetrated at 3831 m and consisted of a 69.5 m thick homogenous sandstone, very\r\nfine to fine grained with poor reservoir characteristics (porosities from 7 to\r\n14 % and permeabilities from 0.3 to 3 mD). All attempts to obtain reservoir\r\npressures and fluid samples failed due to tight formation. Oil shows were\r\nrecorded in the upper half of the reservoir and an oil water contact was\r\nestablished at 3872. Log analysis indicated that no significant hydrocarbons were\r\npresent below the Ula formation where all porous zones calculated high water\r\nsaturations. Weak shows were recorded in sandstone in the interval 3940 to 3960\r\nm in the Skagerrak Formation. Weak shows were recorded also in siltstone in an\r\nisolated sample from 2235 m in the Hordaland Group. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eFour cores were cut from 3844.5 to\r\n3912.15 m in the Ula, Fjerritslev, and Skagerrak formations. Core depths are\r\n4.8 m deeper","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"295","properties":{"OBJECTID":295,"wlbNpdidWellbore":300,"wlbName":"6506/12-7","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 6506/12-7 was drilled as an\r\nexploration well on the Northeast Smørbukk structure. The primary purpose was\r\nto find hydrocarbon accumulations of significant amounts in the Middle and\r\nEarly Jurassic sandstone reservoirs. Secondary objectives were to check for\r\nhydrocarbon accumulations deeper than the structural closure of the main field.\r\nThe well should also verify the geophysical and structural interpretation and improve\r\nthe geological, paleontological and geochemical understanding of the area.\r\nTotal depth was to be in rocks of Triassic age or 4000 m in order to satisfy\r\nthe licence commitment.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 6506/12-7 was spudded with the\r\nsemi-submersible installation Dyvi Delta on 7 April 1987 and drilled to TD at 4840 m in the Early Jurassic Tilje Formation. Drilling proceeded without\r\nsignificant problems. The well was drilled with spud mud down to 597 m, with\r\ngypsum/polymer mud from 597 m to 4427 m, and with a pre-hydrated\r\nBentonite/Lignosulphonate mud system from 4427 m to TD. No shallow gas was\r\nencountered.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe first show appeared in the Lange\r\nFormation at 3791 - 3794 m. During coring there were oil shows in Garn and Ile\r\nFormations, while Ti1je only contained small traces of oil. Both cores and logs\r\nindicated that Garn and Ile Formations were hydrocarbon bearing down to ca 4538\r\nm, while Ti1je Formation was indicated to be water bearing. The porosity was\r\nassumed to be between 8 and 12 %. Mobil wanted to test the Ti1je Formation to\r\nget a fluid sample to understand the logs better. This was a wise decision\r\nbecause the formation produced oil at very good rates. The Garn Formation on\r\nthe other hand did not produce any formation fluid when tested. The oil/water\r\ncontact in the Tilje Formation was not found because the logs did not give\r\nclear data. \u003c/p\u003e\r\n\r\n\u003cp\u003eEight cores were cut in the well with a\r\ntotal recovery of 62.6 m core. One core was cut in the interval 4053 - 4058 m\r\n(Spekk Formation), two cores from 4","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"296","properties":{"OBJECTID":296,"wlbNpdidWellbore":301,"wlbName":"8/1-1","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eExploration well 8/1-1 is situated in the\r\n Danish-Norwegian Basin in the North Sea. The Primary objective of the well was\r\nJurassic to Triassic sands with estimated 380 m gross and 76 m net sand.\r\nSecondary targets were seen in Paleocene sands, Danian - Late Cretaceous\r\nlimestones, and Early Cretaceous sands.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well is Reference Well for the Sauda,\r\nTau, and Flekkefjord Formations.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 8/1-1 was spudded with the\r\n3-leg jack-up installation Ocean Tide on 2 December and drilled to TD at 2973 m\r\nin the Late Permian Zechstein Formation.\u003c/p\u003e\r\n\r\n\u003cp\u003ePaleocene shales were penetrated at 1378\r\nm without sand development. The dark grey shales of the Paleocene continued into the Danian. The interval from 1507 m o 1535 m in the Danian was\r\ndescribed as a light to medium grey calcareous marl grading to shale. The\r\nsequence from 1535 m to 1899 m was composed of white chalky limestone. A bed of\r\nmedium grey to light green-grey shale was recorded from 1899 m to 1932 m. The\r\nEarly Cretaceous consisted of shale and clay. Late Jurassic shales of the Sauda\r\nand Tau Formations were penetarated from 2425 m to 2606 m. The primary target\r\nsands were encountered from 2606 m to 2704 m. Sand and sandstone, clear, white\r\nand light grey, fine medium and coarse grained, angular to sub-rounded and\r\nanhydritic, dominate the lithology. Lesser amounts of medium to dark grey shale\r\noccur in the form of erratically spaced interbeds. Red-brown, silty, soft,\r\nanhydritic shale characterizes the major portion of the Triassic. Interbedded\r\nwith the shale are occasional relatively thin zones of both clear and red\r\nhematitic stained, fine to medium grained, sand. No shows of hydrocarbons were\r\nencountered in either the Jurassic sand or the Danian - Late Cretaceous carbonate.\u00A0\r\nNo conventional core was cut and no fluid samples were taken.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 17\r\nFebruary 1972 as a dry hole.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"297","properties":{"OBJECTID":297,"wlbNpdidWellbore":302,"wlbName":"8/4-1","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 8/4-1 is located in the\r\nDanish Norwegian Basin of the North Sea. The primary objective was to test the\r\nhydrocarbon potential of Middle Jurassic sandstones, expected at 2430 m with a\r\n122 m thickness. A secondary objective was seen in the Late Cretaceous chalk.\r\nPlanned TD was at 2850 m in the Permian Zechstein Group.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 8/4-1 was spudded with the\r\nsemi-submersible installation Norjarl on 21 June 1977 and drilled to TD at 2632\r\nm, 50 m into the Permian Zechstein Group. The well was drilled with lime and\r\nDrispac down to 1757 m and with, and lignosulphonate from 1757 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well encountered a 116 m thick Middle\r\nJurassic sandstones sequence (Bryne Formation) with top at 2397, fairly close\r\nto prognosis. The secondary target was also encountered close to prognosis, at\r\n1664 m (Tor Formation). Early Cretaceous Cromer Knoll Group was found\r\nunconformable on Late Jurassic shales. The Upper part of the Boknfjord Group\r\nwas not present in the well. The well was electrically logged from 85 m to 2623\r\nm and no pay was present in the well to this depth. Trace residual oil shows\r\nwere seen in sidewall cores at 2417 m and 2462 m. Total gas averaged 5 to 10\r\nunits throughout the course of drilling with no significant gas peaks. Shows of\r\nthe heavier hydrocarbon gases C2 to C4 were present in the interval 2355 m to\r\n2466 m. Three pressure regimes exists in this well. The first includes the Late\r\nTertiary sediments and is only very slightly overpressured reaching approximately\r\n9.2 ppg at its base at 899 m. This is the top of the second regime and marks\r\nthe unconformity between the Late Tertiary and Eocene sediments. The Eocene and\r\nthe Paleocene below, exhibit an increasing pore pressure with depth reaching a\r\nmaximum of approximately 12.6 ppg EMW above the Paleocene/Late Cretaceous\r\nunconformity at 5261 ft. (1604 m). The third regime extends to TD and is\r\nassumed to be near normally pressured. Organic geo","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"298","properties":{"OBJECTID":298,"wlbNpdidWellbore":303,"wlbName":"8/9-1","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 8/9-1 is located in the Åsta Graben.\r\nIt was designed to test a salt structure in the central part of the\r\nNorwegian-Danish basin. The primary objective was to penetrate Basal Jurassic\r\nunconformity sands in a crestal position of the closure. The sands were\r\nestimated to have an approximate gross thickness of 60 m and were expected to\r\nbe Late Jurassic in age. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe well is Reference Well for the\r\nFiskebank Formation.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 8/9-1 was spudded with the\r\nsemi-submersible installation Ocean Viking on 22 December 1975 and drilled to\r\nTD at 2376 m in the Late Permian Zechstein salt. The well was drilled with salt\r\ngel down to 411 m and with a lignosulphonate / gypsum mud from 411 m to TD. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe well penetrated fine-grained silty\r\nsandstone very rich in glauconite in the interval 1316 m to 1376 m in\r\nPaleocene. Net sand for the interval was 60 m and porosities derived from the\r\ndensity log and corrected for clay effects were in the range 16 % to 24 %. In\r\nthe interval 2124 m to 2149 m in the Late Jurassic a series of interbedded\r\nclaystones, siltstones and sandstones were penetrated. The only true sandstone\r\ninterval here existed between 2147 m and 2149 m where porosities ranged from 7\r\n% to 14% calculated from density - neutron cross plot. All other low GR and\r\npermeable intervals in the Late Jurassic section indicated porosities\r\nsubstantially less than this and corresponding sidewall cores showed tight\r\nsiltstones. In the Middle Jurassic the interval 2168.7 m to 2222.6 m was found\r\nto contain a sequence of predominantly interbedded sandstones, siltstones, and\r\nclaystones with occasional thin carbonaceous beds. The caliper indicated a net\r\nsand of approximately 25 m out of a gross interval of 54 m. The porosities in\r\nthis interval were exceedingly variable from one sandstone unit to the next and\r\nranged from 5 % to 26 %. The sands with the highest porosities occurred near\r\nthe top of the section between 2171 m a","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"299","properties":{"OBJECTID":299,"wlbNpdidWellbore":304,"wlbName":"8/11-1","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 8/11-1 is located on the\r\nSørvestlandet High towards the Åsta Graben. It was drilled on a crestal\r\nposition of an elongated faulted anticline approximately 11 km long and 5 km\r\nwide. The primary objective horizon was the Jurassic Sandstone section, which\r\nfrom seismic information was expected to have closure of 39 km2 with a maximum\r\nof 66 m of vertical closure. Late Cretaceous limestone, Paleocene sandstone and\r\nTriassic Sandstone were secondary objectives.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 8/11-1 was spudded with the\r\nsemi-submersible installation Ocean Viking on 24 April 1975 and drilled to TD\r\nat 3810 m in the Triassic Red beds. The well was drilled with seawater and\r\nAttapulgite clay down to 458 m, with seawater/Drispac and 3% diesel oil from\r\n458 m to 1219 m, and with seawater/Drispac/lime/4-5% diesel oil from 1219 m to\r\nTD. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe formation tops and thicknesses agreed\r\nwell with the geological prognosis with Paleocene coming in at 1968 m, top\r\nCretaceous at 2143 m, the Jurassic at 2807 m, and top Triassic in the interval\r\n2855 m to 2900 m. In the Paleocene, no sands were developed and in the Upper\r\nCretaceous the limestone was tight. The Jurassic section consisted of 27.4 m of\r\ndark grey shale of Portlandian - Late Kimmeridgian age. The total sand section\r\nhad been eroded away by the Kimmeridgian unconformity. After drilling 975 m of\r\nbarren Triassic section the well was terminated at the prognosed depth of 3810\r\nm without the Zechstein salt having been encountered. The well had no shows and\r\nthus no testing was carried out. No conventional core was cut and no fluid\r\nsample taken. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 29\r\nJune 1975 as a dry well.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was performed\u003c/p\u003e\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"300","properties":{"OBJECTID":300,"wlbNpdidWellbore":305,"wlbName":"9/4-4","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 9/4-4 is located east of the\r\nFlekkefjord High on the western flank of the Egersund Sub-basin, which forms a\r\npart of the Danish-Norwegian Basin. The main objective of drilling 9/4-4 was to\r\ntest the middle Jurassic sands on the western flank of the Egersund sub-basin.\r\nAlternating porous and nonporous sands of Late Triassic and possible minor Late\r\nJurassic sands were considered secondary objectives.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 9/4-4 was spudded with the\r\nsemi-submersible installation Deepsea Saga on 19 July 1977 and drilled to TD at\r\n2902 m, 57 m into the Triassic Skagerrak Formation. No significant problems\r\nwere encountered in the drilling operations. The well was drilled with\r\nhigh-viscosity spud mud down to 405 m, with gypsum mud from 405 m to 1300 m,\r\nand with lignosulphonate mud from 1300 m to TD. At 2807 m the pipe stuck and\r\nwas freed by adding "Pipefree" and diesel to the mud.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe Middle Jurassic sands with a gross\r\nthickness of 117 m were found as postulated. Secondary objective reservoir\r\nsands in Late Triassic and Late Jurassic were not encountered. No oil shows\r\nwere encountered in any section of the well and no hydrocarbons could be\r\ninferred from logs. The most likely reason for the lack of hydrocarbons is\r\nimmaturity of the Jurassic source beds. Organic geochemical source rock\r\nscreening of the interval 250 m to TD showed good to excellent source rocks in\r\nthe Late Jurassic shales and the Middle Jurassic (Bryne Formation) coals. The\r\nanalyses showed that the Bryne coals were immature for petroleum generation and\r\nthat the Late Jurassic shales were immature, possibly marginally mature. No\r\nconventional core was cut and no fluid samples taken. Fourteen sidewall cores\r\nwere recovered from the interval 2673 m to 2850 m.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 20\r\nAugust 1977 as a dry hole.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was performed.\u003c/p\u003e\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"301","properties":{"OBJECTID":301,"wlbNpdidWellbore":306,"wlbName":"10/5-1","wlbHistory":"\r\n\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 10/5-1 was designed to test a tilted\r\nfault block with an overlying pinch out trap in the eastern part of the\r\nNorwegian-Danish basin. The primary objective was Rotliegendes sands. A\r\nprobable 460 m gross thickness was anticipated. A secondary objective was\r\nMiddle Jurassic sandstones with an estimated gross thickness of 61 metres.\r\nOther possible objectives were the Early Cretaceous sandstones and Basal\r\nZechstein carbonates.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well is Illustration Well for the\r\nBørglum Unit of the BoknFjord Group.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eExploration well 10/5-1 was spudded with\r\nthe semi-submersible installation Norjarl on 31 May 1976 and drilled to TD at\r\n1843 m in crystalline granite dated by the potassium-argon method to apparently\r\n689 ± 21 My (Late Precambrian). After drilling the 36" section to 189 m\r\nthe hole had washed out under the temporary guide base. The guide base sank 26\r\nfeet below the mud line and the 30" casing could not be stabbed through\r\nthe guide base. The rig was moved 38 m and the hole was respudded. The well was\r\ndrilled with seawater / gel down to 501 m, with Inpac polymer mud from 501 m to\r\n1768.2 m, and with lignosulphonate mud from 1768.2 m to TD. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe well penetrated a gross thickness of\r\n67 metres of Middle Jurassic (Sandnes Formation) sandstones from 1472 m to 1539\r\nm. Porosity was good, but there were no hydrocarbon indications while drilling,\r\nand subsequent log analysis confirmed that the objective horizons were water\r\nwet. Triassic sandstones were also encountered, but these were extremely\r\nshaley, and had no clean sandstone sections. Rotliegendes sandstones were not\r\npresent at the 10/5-1 location. The base of the Zechstein interval was\r\nrepresented by a clear, white, light brown, hard, very angular sandstone,\r\ncemented with siliceous cement and extremely tight. Organic geochemical\r\nanalyses found fair to rich TOC (1 - 5%) in the Early Cretaceous and Late\r\nJurassic and possibly in some Permian sha","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"302","properties":{"OBJECTID":302,"wlbNpdidWellbore":307,"wlbName":"11/9-1","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 11/9-1 is located in the Horn Graben\r\nfar to the east in the North Sea towards the Skagerrak Sea, ca 15 km from the\r\nDanish border. It was located near the top of a saliferous structure in order\r\nto explore the whole Triassic series in the most favourable structural\r\nposition. The structure is potentially large, but since all horizons above the\r\nJurassic level were expected to crop out on the seabed the objective horizon\r\nwas Lower Middle Triassic carbonaceous shales. These shales were seen both as\r\nsource rock and seal for hydrocarbons in underlying sandstones (basal Triassic\r\nBrockelschiefer). No other objectives were defined for this well. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 11/9-1 was spudded with the\r\nsemi-submersible installation Deepsea Driller on 16 January 1976 and drilled to\r\nTD at 1972 m, 42 m into Late Permian Zechstein salt. The well was drilled water\r\nbased with spud mud down to 660 m and with ferrochrom lignosulphonate mud (FCL)\r\nfrom 660 m to TD. \u003c/p\u003e\r\n\r\n\u003cp\u003eDrilling was without returns to 145 m.\r\nFrom there red sandstones and variegated shales made up a very thick Triassic\r\ninterval (1785 m). The Triassic contained reservoirs as usual but no obvious\r\nsealing intervals were seen. Moreover, no potential source rocks were\r\nencountered. No shows of gas or oil were recorded during drilling and the\r\ndifferent reservoirs were water bearing from the logs. No conventional core was\r\ncut and no fluid sample taken. Forty sidewall cores were retrieved in two runs\r\nin the interval 737 m to 1962 m. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 28\r\nFebruary 1976 as a dry hole.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was performed.\u003c/p\u003e\r\n\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"303","properties":{"OBJECTID":303,"wlbNpdidWellbore":308,"wlbName":"15/2-1","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 15/2-1 was drilled in the Vilje\r\nsub-basin in the Viking Graben in the North Sea, ca 1.5 km from the UK border.\u003c/span\u003e\u003cspan lang=EN-GB\u003eThe objective of the well 15/2-1 was to\r\ntest the Upper Jurassic, Middle Jurassic, and Triassic sandstone reservoirs\r\nnorthwest of and down dip of the salt diapir encountered in the well 15/5-3. The\r\nwell was planned to be drilled ca 200 m into the Triassic with a total depth of\r\nca 4525 m.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 15/2-1 was spudded with the\r\nsemi-submersible installation Nortrym on 26 September 1981 and drilled to TD at\r\n4600 m in the Late Permian Zechstein Group. No significant problems were\r\nencountered in the operations. The well was drilled with seawater and hi-vis\r\npills down to 665 m and with Shaletrol polymer mud system from 665 m to 2750 m.\r\nAt 2750 m the mud was converted to a dispersed mud system by adding\r\nlignosulphonate and this was used for the remaining well bore down to TD. There\r\nwas 0 - 3% oil in the mud below 1168 m.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well penetrated a number of sandstone\r\nFormations in the Tertiary (Skade, Grid, Intra Balder sandstone, Heimdal, and\r\nTy Formations). All these were entirely water wet. The Hugin Formation (4356 - 4493\r\nm) consisted of massive very fine grained sandstones with beds of coal on top. The\r\nSleipner Formation (4493 - 4554.5 m) had a 10 m thick coal layer on top\r\nunderlain by siltstones grading occasionally to very fine sandstones, interbeds\r\nof sandstones, and stringers of coal. The well did not penetrate any Early\r\nJurassic or Triassic rocks, but encountered evaporites of Permian age at 4554.5\r\nm, unconformably underlying the Sleipner Formation.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eGood hydrocarbon shows were reported from\r\nboth the Hugin and Sleipne","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"304","properties":{"OBJECTID":304,"wlbNpdidWellbore":309,"wlbName":"15/3-1 S","wlbHistory":"\u003chtm\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 15/3-1 S was drilled west of the\r\nGudrun Terrace on the east flank of the North Sea Central Graben. The primary\r\nobjective was to test sands in the Middle Jurassic (Dogger sands). Secondary objectives\r\nwere the Early Tertiary, Danian, Early Cretaceous sands. Triassic sandstones\r\nand Zechstein dolomites down to the "economic basement" were also\r\npossible targets. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well is reference well for the Ty,\r\nDraupne, and Heather formations.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 15/3-1 S was spudded with\r\nthe semi-submersible installation Deepsea Driller on 27 November 1974 and\r\ndrilled without significant problems to 4400 m. While circulating before\r\nlogging the pipe stuck and the hole started to kick. After unsuccessful efforts\r\nto free the pipe the well was plugged back and sidetracked from 3985 m. The\r\nsidetrack was drilled without further significant problems to final TD at 5129\r\nm in the Middle Jurassic Hugin Formation. \u00A0\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well penetrated water-bearing Hermod,\r\nHeimdal and Ty formation sandstones from 2215 to 2715 m. The Ty Formation from\r\n2556 m was reported as the best of these with a main body of clean sand from\r\n2599 to 2711 m. Top Viking Group, Draupne Formation was encountered at 3947 m.\r\nThe Draupne Formation contained many oil and gas bearing Intra-Draupne\r\nFormation sandstones. Of these the best reservoirs were found in the intervals\r\n4083 to 4317 m with OWC at 4218 m, and 4442.5 to 4610 m with OWC at 4486 m.\r\nTotal net pay in these two intervals together were 32 m with 22 - 19 %\r\nporosity. Geochemical analyses indicated good source rock properties in the\r\nshale interbeds, with a maturity ranging from early to late oil window\r\n(vitrinite reflectance from 0.6 to 0.9 %R","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"305","properties":{"OBJECTID":305,"wlbNpdidWellbore":310,"wlbName":"15/3-2","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 15/3-2 was drilled in the Vilje\r\nsub-basin structural element of the south Viking Graben of the North Sea. The\r\nobjectives of well 15/3-2 were all Jurassic sands. The well was planned in two\r\nphases. Phase 1 (15/3-2) was to be drilled with the Polyglomar Driller down to\r\ntop Jurassic. Phase 2 (15/3-2 R) was to be drilled with the Pentagone 84, a rig\r\nwith a 15.000 psi wellhead equipment, necessary for testing of the high-pressure\r\nJurassic reservoirs.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 15/3-2 was spudded with the\r\nsemi-submersible installation Polyglomar Driller on 29 October 1976 and drilled\r\nto TD at 4258 m in the Late Jurassic Draupne Formation. When pulling out of the\r\nhole to set the 9 5/8" casing the drill string parted at 138 m, but was\r\nfished out. Otherwise, no significant technical problem occurred in the\r\noperations. The well was drilled with seawater and hi-vis pills down to 186 m,\r\nwith prehydrated bentonite in fresh water from 186 m to 784 m, with LFC/Dextrid\r\nmud from 784 m to 2875 m, and with LFC+LC in seawater from 2875 m to TD. Up to\r\n3% oil was added to the mud from 3953 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eDown to 4236 m (Tertiary and Cretaceous\r\nsections) no significant shows were observed except in Coniacian and Turonian\r\nlimestones where some brown-yellow fluorescence was observed. Electric log\r\nanalysis did not indicate any hydrocarbon-bearing reservoirs in these\r\nlimestones. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo cores were cut and no wire line pressure\r\npoints or fluid samples were taken.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eA 9 5/8" casing was set at 4248 m\r\nand the well was suspended on 24 January 1977 for later re-entry and drilling\r\nand testing of","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"306","properties":{"OBJECTID":306,"wlbNpdidWellbore":311,"wlbName":"15/3-2 R","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 15/3-2 R is a re-entry of well\r\n15/3-2 in the Vilje sub-basin structural element of the south Viking Graben of\r\nthe North Sea. The primary well 15/3-2 was drilled by "Polyglomar\r\nDriller", which was equipped with 10.000 psi WP 18 3/4" BOP-stack.\r\nThis well was suspended on 24 January 1977 with 9 5/8" casing set at 4248\r\nm, in the Late Jurassic Draupne Formation. The re-entry was drilled with the\r\nPentagone 84, equipped with a 15000 psi WPI 11" BOP stack, necessary to drill\r\nand test high-pressure Jurassic reservoirs. The objective of well 15/3-2 R was\r\nto test the Jurassic reservoirs, including the Dogger - Lias sections.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 15/3-2 was re-entered with the\r\nsemi-submersible installation Pentagone 84 on 26 July 1977 after some initial\r\nproblem with connecting to the wellhead on the sea floor. An 8 11/32" hole\r\nwas drilled down to 4990 m when the drill string parted. In spite of an\r\nextensive fishing operation, the fish had to be left in hole. Top fish is at\r\n4742 m. A sidetracking operation was performed trying to bypass the fish, but\r\nalso this operation failed and 4990 became TD of the well. The well was drilled\r\nwater based with LFC-LC mud from re-entry point to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe Draupne Formation extended from 4236\r\nm down to 4352 m, making up a total of 116 m. Geochemical analyses proved TOC\r\nfrom 3 to 7 %wt and vitrinite reflectance analyses indicated middle oil window\r\nmaturity (%Ro = 0.75). Four Intra Heather Formation sandstone reservoirs were\r\ndrilled in the Jurassic section, varying in gross thickness from 15 to 112 m. According\r\nto logs the two upper ones, 112 and 64 m thick, were hydrocarbon-bearing, but\r\nwith bad characteristic","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"307","properties":{"OBJECTID":307,"wlbNpdidWellbore":312,"wlbName":"31/4-8","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 31/4-8 was drilled on the Brage\r\nfield in the North Sea to appraise the Statfjord Group oil discovery made in\r\nwell 31/4-7. The Cook Formation of the Dunlin Group was the secondary target.\r\nThis sandstone was found water bearing in well 31/4-7. Chances for finding\r\nhydrocarbons in well 31/4-9 were good since the formation would be penetrated\r\nin a structurally higher position. Prognosed TD was 2565 m or 50 m into\r\nTriassic rocks.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 31/4-8 was spudded with\r\nthe semi-submersible installation Treasure Hunter on 11 May 1986 and drilled to\r\nTD at 2611 m in the Late Triassic Lunde Formation. The 13 3/8" casing got\r\nstuck at 1855 m. Diesel and spot fluid was pumped down the hole and the casing\r\nwas worked free. The well was drilled with spud mud down to 900 m and with\r\nKCl/polymer mud from 900 m to TD. From 2030 m to ca 2400 m the KCl/polymer mud\r\ncontained 1% diesel as a result of the problem with the stuck casing.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well 31/4-8 encountered hydrocarbon\r\nbearing sandstones and siltstones in the Viking Group, the Statfjord Group and the\r\nLunde Formation. Of these, only the Statfjord reservoir is produceable. The\r\nViking Group consisted of a thin Draupne Formation from 2085 m to 2088 m and a\r\n29 m thick Fensfjord Formation with poorly developed, generally very fine-fine\r\nsandstones grading into and interbedded with siltstones and claystones. Some\r\nresidual hydrocarbons were encountered in the best sands. Net pay in the\r\nFensfjord Formation was 0.61 m, water saturation was 59.9% and the average porosity\r\nwas 25.5%. The Cook Formation was found water bearing without traces of shows. Average\r\nporosity in the Cook sand was 17.7%. The Statfjord Group had a gross oil column\r\nof 60 m from 2346 to the OWC at 2406 m.","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"308","properties":{"OBJECTID":308,"wlbNpdidWellbore":313,"wlbName":"15/3-3","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 15/3-3 was drilled west of the\r\nGudrun Terrace on the east flank of the North Sea Central Graben, about 4.5 km north-east\r\nof the 15/3-1 S discovery. The main objective of the 15/3-3 well was to appraise\r\nthe complete Jurassic series up-dip of well 15/3-1 S drilled on the same\r\nstructure in 1975. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 15/3-3 is type well for the Grid\r\nFormation.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 15/3-3 was spudded with\r\nthe semi-submersible installation Pentagone 84 on 5 January 1979 and drilled to\r\nTD at 5115 m in the Triassic Skagerrak Formation.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eSeveral water bearing sands with high\r\nporosity were encountered in the Tertiary section including the Grid, Heimdal\r\nand Ty formations. The Cretaceous had no reservoir sections and was drilled\r\nwithout gas shows. The Late Jurassic Draupne Formation was encountered at 4017\r\nm. The Draupne Formation was 208 m thick and consisted of shales with only a\r\nfew < 1 m sandstone beds. The Heather Formation was penetrated from 4225 to\r\n4522 m and contained a main Intra Heather Formation sandstone from 4260 to 4369\r\nm. This sandstone was gas and condensate bearing in the upper part down to a\r\nGOC at 4272 m. The Hugin Formation came in at 4522 m and then the Sleipner\r\nFormation at 4545 m. The Hugin Formation contained gas filled sandstone from\r\n4522 to 4527 m. Several thinner sandstones with gas followed down to a main gas\r\nfilled sandstone in the Sleipner Formation from 4588 to 4632 m. A second hydrocarbon\r\nfilled Sleipner Formation sandy interval was penetrated from 4679 to 4693 m.\r\nThe upper part down to 4687 m consisted of good sandstone, further down it was\r\ncemented.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe only oil shows in the well was rare\r\npa","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"309","properties":{"OBJECTID":309,"wlbNpdidWellbore":314,"wlbName":"15/3-4","wlbHistory":"\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 15/3-4 was drilled on the Gudrun\r\nTerrace, east of the 15/3-1 S Gudrun Discovery in the North Sea. The main objective\r\nof the well was to test sandstones of the Late and Middle Jurassic, which were\r\nfound to contain gas and condensate in wells 15/3-1 S and 15/3-3. The secondary\r\ntarget was the Eocene sands where oil shows were encountered in well 15/5-3. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 15/3-4 was spudded with the\r\nsemi-submersible installation Borgsten Dolphin on 3 October 1981and drilled to\r\nTD at 4259 m in the Triassic Skagerrak Formation. After the 13 3/8" casing\r\nhad been cemented drilling was interrupted for 13 days due to a combination of\r\nbad weather and repairs on the BOP stack. When running in hole at TD the drill string\r\nstuck leaving a fish with top at 4098 m. Hence, no logs were run between 4098 m\r\nand TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe Eocene sands from 1628 to 2025 m\r\n(Grid Formation sands) were found water bearing. The Brent Group was\r\nencountered with top Hugin Formation at 3786 m and top Sleipner Formation at\r\n3856 m. Sandstones in the Brent Group contained oil and gas in four different intervals:\r\n3786 to 3817 m, 3819.5 to 3826.5 m, 3849.9 to 3854.8 m, and 3872.2 to 3876.4 m.\r\nThe four zones were in different pressure regimes. The interval from 3819.5 to\r\n3826.5 m had a low hydrocarbon saturation based on the logs, but the cores from\r\nthis section had good shows with a similar bulk hydrocarbon composition as in\r\nthe uppermost interval. Triassic sands below 4050 m were found water bearing. Good\r\noil shows were seen on all cores from the Hugin Formation, otherwise no shows\r\nwere reported from the well.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eFive cores were cut in the well. Core 1\r\nwas cut in the Grid Formation from 1678 to 1694 m wit","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"310","properties":{"OBJECTID":310,"wlbNpdidWellbore":315,"wlbName":"15/5-1","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 15/5-1 was drilled on the Ve\r\nSub-basin north of the Sleipner Vest Field in the North Sea. The main objective\r\nof the well was to test sandstone reservoirs of Middle Jurassic age. In the\r\nnearby Sleipner field (in block 15/6 and 15/9) gas had been found previously in\r\nreservoirs of the same age. The well was located down flank on the structure at\r\nthe Kimmerian level. This position was chosen to penetrate reservoirs believed\r\nto be wedging both above and below a strong seismic marker ("Red\r\nMarker").\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 15/5-1 was spudded with the\r\nsemi-submersible installation Treasure Seeker on 26 November 1977 and drilled\r\nto TD at 3775 m in Late Triassic sediments belonging to the Hegre Group. This\r\nwas the first well drilled by Treasure Seeker, which was outfitted in\r\nStavanger. About 25% of total rig time was counted as lost time, mainly due to\r\nwait-on-weather or equipment problems caused by rough weather in wintertime.\r\nThe well was drilled with seawater and gel down to 1225 m, with\r\nseawater/gel/CMC/Spersene from 1225 m to 1910 m, and with a freshwater-based Spersene/gel/chrome-lignosulphonate/Drispac\r\nmud from 1910 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe 15/5-1 well encountered gas\r\ncondensate-bearing sandstones of Late and Middle Jurassic age (Callovian and\r\nBathonian) from top at 3558 m down to 3614 m where a Bathonian/Bajocian deltaic\r\nseries with up to five m thick coal beds appeared. From wireline log evaluation\r\nthe sandstone section with a gross thickness of 56 m, has been subdivided into\r\nfour separate pay zones, each zone being separated by thin impermeable layers,\r\nresulting in a net sand pay of 42.1 m. Average porosity was calculated to 14%\r\nand the average water-saturation to 14%. Sands were water wet below the coal\r\nbed","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"311","properties":{"OBJECTID":311,"wlbNpdidWellbore":316,"wlbName":"15/5-2","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 15/5-2 was drilled in the Ve Sub-basin\r\nin the North Sea, north of the Sleipner Vest Field and 15/5-1 Gina Krog\r\nDiscovery. The main objective of the well was to test possible hydrocarbon\r\naccumulations in Middle to Late Jurassic Bathonian/Callovian transgressive\r\nsandstones and Middle Jurassic Bajocian deltaic sandstones. The well was\r\nlocated in a purposely off-crestal position on an approximately 16 km2 large\r\nstructure some 7 km north-west of the 15/5-1 discovery.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was planned to penetrate into\r\nthe Triassic with a projected total depth of 4500 m. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 15/5-2 was spudded with the\r\nsemi-submersible installation Treasure Seeker on 16 August 1978 and drilled to\r\nTD at 4322 m in the Triassic Hegre Group. At 1267 m, the string unscrewed in a\r\ntight section, but it was fished without problems. After drilling to 2293 m,\r\nthe string stuck when pulling out of hole. This time the fish was not recovered\r\nand a sidetrack was performed with kick-of at 1775 m. Heavy weather caused\r\nfurther delays, otherwise the drilling went forth without significant problems\r\nto TD. The well was drilled with seawater mud mixed with gel and Spersene down\r\nto 454 m, and with a Spersene/XP-20 (lignosulphonate) mud from 454 m to TD. At\r\n2232 m 1% Diesel was added to the mud. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eTwo hydrocarbon bearing sandstone\r\nintervals were penetrated by the well. In the Jurassic, only a thin Early to\r\nMiddle Bathonian sandstone development was penetrated between 4035 m and 4055 m.\r\nInterbeds of siltstones and shales reduced the 20 m gross pay to a net pay of\r\n7.3 m from wireline log interpretation. Average porosity and average water\r\nsaturation over the pay interval was calculated to 14.3 and 41","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"312","properties":{"OBJECTID":312,"wlbNpdidWellbore":317,"wlbName":"15/6-2","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 15/6-2 was drilled in the Ve\r\nSub-basin in the North Sea, ca 5 km north of the Sleipner Field. It is the\r\nreplacement well for 15/6-1, which was junked for technical reasons. The objective\r\nwas to evaluate a deep-seated structure in the Scottish-Norwegian Graben. The\r\ntarget was Eocene to Paleocene sandstones.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 15/6-2 was spudded with the drill\r\nvessel on 9 September 1971 and drilled to TD at 3131 m in the Shetland Group. No\r\ndrilling problems were encountered, however, due to deviation problems around 1311\r\nm a planned FIT was aborted, as the tool would not go beyond this depth. Initial\r\ndrilling from the sea floor to 1330 m was with seawater and gel. Below 1330 m,\r\na fresh water Spersene XP-20 mud system was used. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe Paleocene section contained abundant\r\npotential sandstone reservoirs (Heimdal Formation) with thin beds of clay\r\nbecoming marly below 2390. Significant shows were encountered in the interval 2223\r\nto 2236 m in the upper Heimdal Formation. The cuttings, sidewall and\r\nconventional cores corroborated the shows. Weak shows were recorded also on\r\nnumerous sidewall cores between 2303 and 2604 m. However, other evidence did\r\nnot substantiate these shows and the reservoir was assumed water wet below 2236\r\nm. The Danian (2676 to 2735 m, Våle Formation) consisted of a sequence of\r\nthinly interbedded sandstones, clays, shales and chalky limestones. No shows\r\nwere reported in this section. The Late Cretaceous section, from 2735 m to 3106\r\nm, was predominantly limestone with thin interbeds of shale. Thin interbeds of\r\nsandstone were also noted. There were no shows in the Late Cretaceous.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThree cores were cut. Core 1 was cut from\r\n2236 to 2242 m with 10","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"313","properties":{"OBJECTID":313,"wlbNpdidWellbore":318,"wlbName":"15/6-3","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 15/6-3 was drilled in the Ve\r\nSub-basin in the south Viking Graben in the North Sea. The primary objective\r\nwas to test the Dogger Sands (Middle Jurassic), which were gas bearing in\r\n15/6-2 R, at a structurally higher position on a large north south trending\r\nanticline.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 15/6-3 was spudded with the semi-submersible\r\ninstallation Drillmaster on 5 September 1974 and drilled to TD at 3795 m in\r\nLate Triassic sediments of the Skagerrak Formation. A lignosulphonate seawater\r\nmud was used to drill the well. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe Dogger sand from top at 3488 m to 3579\r\nm was hydrocarbon bearing. The resistivity log indicate gas down to a massive\r\ncoal layer at ca 3562 m. The true gas/water contact was not established. There was\r\n63 m of net gas bearing sand with average porosity 21% and average water\r\nsaturation 21.%. The Triassic was not a viable reservoir. The only major shows in\r\nthe well were in the Dogger reservoir sands.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eA total of 125.8 m core was recovered\r\n(90.7 % overall recovery) in ten cores in the interval 3512.2 to \u00A03650.9 m. FIT\r\nfluid samples were taken at 3505 m (gas, water, mud\u00A0 and trace oil), 3553 m\r\n(gas, water, mud and trace oil), 3557 m (gas, mud filtrate and mud), and 3575 m\r\n(mud filtrate and mud).\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was permanently abandoned on 19\r\nDecember 1974 m as a gas/condensate discovery.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eTesting\u003c/span\u003e\u003c/b\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eTwo production tests were run.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe first was between 3601.2 and 3604.3 m,\r\nthis failed to flow. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyT","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"314","properties":{"OBJECTID":314,"wlbNpdidWellbore":319,"wlbName":"15/6-4","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 15/6-4 was drilled on the southern\r\nend of the Gudrun Terrace in the North Sea. The objective was to test the\r\nhydrocarbon potential of Middle Jurassic (Dogger) sandstones.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 15/6-4 was spudded with the\r\nsemi-submersible installation Norjarl on 28 June 1976 and drilled to TD at 3505\r\nm in the Triassic Smith Bank Formation. The well was drilled water based with\r\nlignosulphonate/CMC/lignite below 3097 m\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eTop Draupne Formation was encountered at 3157\r\nm. The target sandstone unit was encountered at 3222 m and was found to be\r\nwater bearing.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eFour cores were cut. Cores 1 and 2 were\r\ncut from 3226.3 m to 3247.6 m and cores 3 and 4 were cut from 3271.5 m to 3308\r\nm. FIT fluid samples were taken on wire line at 3312 m (small amounts of gas\r\nand 10.2 l water) and at 3222.5 m (small amounts of gas and 10.2 l water).\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was permanently abandoned on 16\r\nAugust as a dry well.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eTesting\u003c/span\u003e\u003c/b\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo drill stem test was performed.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"315","properties":{"OBJECTID":315,"wlbNpdidWellbore":320,"wlbName":"15/6-5","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 15/6-5 was drilled in the north-eastern\r\npart of the Sleipner Field (Sleipner West). The objective was to confirm\r\nstructural and stratigraphic interpretations as well as define the hydrocarbon\r\ncontent and contacts and the reservoir properties in this part of the Field.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well is reference well for the Hugin\r\nFormation.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 15/6-5 was spudded with\r\nthe semi-submersible installation Drillmaster on 10 October 1977 and drilled to\r\nTD at 3824 m in Triassic sediments. No significant problems were encountered\r\nduring the drilling of the well. Initial drilling from the sea floor to 166.5 m\r\nwas with fresh water and lignosulphonate. Below this depth and down to 1197.5 m\r\na seawater gel with carboxymethyl-cellulose (CMC) mud system was used. Below\r\n1197.5 m the above mud with lignosulphonate was used.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe Hugin Formation (Upper Dogger\r\nSandstone) was encountered at 3627 meters. This was six meters below the lowest\r\ngas seen in the main Sleipner reservoir to that date, 3597 m MSL in 15/9-1. The\r\nHugin Formation is 53 meters thick in the well and essentially 100% sandstone. Electric\r\nlog analysis and RFT pressure data show the section to be water bearing,\r\nalthough the presence of residual hydrocarbons down to 3655 m was indicated by\r\nbleeding gas and excellent liquid hydrocarbon shows in the cores. No\r\nhydrocarbon indications were present below 3655 m. The Sleipner Formation\r\n(Lower Dogger) came in at 3580 m with several massive coals beds. The well established\r\nthat the potential lower limit of hydrocarbons in the main Sleipner reservoir was\r\n3627 m (3603 m MSL). \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eFour conventional cores were cut from\r\n3629 m to","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"316","properties":{"OBJECTID":316,"wlbNpdidWellbore":321,"wlbName":"15/8-1","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 15/8-1 was drilled west of\r\nthe Sleipner field, ca 2 km from the UK border. The well was designed to test\r\npossible hydrocarbon accumulation in the sandstones of middle Jurassic age.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 15/8-1 was spudded with the\r\nsemi-submersible installation Glomar Biscay II on 18 July 1981 and drilled to\r\nTD at 4300 m in the Middle Jurassic Fladen Group. Drilling operations were\r\nperformed without significant problems in the 36", 26" and 17 1/2"\r\nholes. Pipe stuck in the 12 1/4" hole at 2254 m and several times in the 8\r\n1/2" hole. Miscellaneous technical problems occurred while drilling the\r\n6" hole and a gas kick was at 4265 m while tripping. The well was drilled\r\nwith seawater and gel down to 500 m and with gypsum mud from 500 m to 2890 m.\r\nLignosulphonate was added from 1570 m, and from 2890 m to TD the gypsum mud was\r\ngradually depleted and replaced with a gel/lignosulphonate mud.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well 15/8-1 proved gas and condensate\r\nin sandstone of Middle Jurassic age. The gas/water contact was indicated at\r\n3698 m from the Formation Multi Tester. Oil shows were recorded from 3065 m to\r\n3075 m in the Hod Formation. Five conventional cores were cut in the interval\r\n3658 m to 3705.5 m in the Hugin Formation. Three samples were attempted taken\r\nduring FMT runs. Due to technical malfunctions only 1 sample (from 3668 m) was\r\nobtained.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 7\r\nJanuary 1982 as a gas/condensate discovery.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eOne drill stem test was performed in the\r\nSleipner formation and three in the Hugin Formation. The procedure of the tests\r\nwas similar; after initial flow and build up the well was flowed for\r\napproximately 660 min. producing gas/condensate. Test no. 4 was only flowed for\r\n480 minutes. CO2 was produced in all tests, in concentrations ranging from 4%\r\nto 15%, and up to 8 ppm H2S was recorded in DST2. Two sets of PVT samples were\r\ntaken ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"317","properties":{"OBJECTID":317,"wlbNpdidWellbore":322,"wlbName":"15/9-1","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 15/9-1 is located in the Sleipner\r\nField. It was drilled on a seismic structure in order to evaluate the Dogger\r\nsandstone (Hugin and Sleipner Formations) of Middle Jurassic age.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 15/9-1 was spudded with the\r\nsemi-submersible installation Ross Rig on 24 February 1977 and drilled to TD at\r\n3734 m in the Late Triassic Skagerrak Formation. Severe weather occurred on 31\r\nMarch, at 3539 m, when the drill string was hung off in the wellhead and the lower\r\nmarine package disconnected. Drilling commenced on 2 April. When\r\nwashing/reaming back to TD at 3675 m with a bit to open up the rat hole the\r\npipe stuck at 3647m. Jarring/fishing action was unsuccessful and the string was\r\nbacked off at 3507 m. The hole was then plugged back, sidetracked and drilled\r\nto TD. The well was drilled with seawater and hi-vis pills to 415.5 m and with\r\na seawater/conditioned bentonite/spersene mud system from 415.5 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eTop of the Dogger sandstone (Hugin\r\nFormation) was encountered at 3530 m. Log evaluation gave a net productive pay\r\nof 56 m, of which 38 m was gas bearing and 18 m was oil bearing. Lowest\r\nproducible hydrocarbon depth was top of coal bed at 3672 m. Good shows were\r\nrecorded on cuttings in the interval 3633 m to 3687 m, and in porous sandstones\r\non cores from 3545 m to 3667 m. The Jurassic sandstone was cored in nine cores\r\nbetween 3521 m and 3675.5 m. RFT fluid samples were taken at 9 depths in the\r\ninterval 3525.5 m to 3701 m. Most of them recovered traces of condensate or oil\r\ntogether with mud filtrate and gas. Only three samples recovered measurable\r\nquantities of fluid hydrocarbons: 3528.8 m (5 - 15 ml condensate), 3596.5 m\r\n(500 ml condensate), and 3621 m (5 - 15 ml oil). \u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 30\r\nMay 1977 as an oil and gas appraisal.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eTwo DST's were performed. \u003c/p\u003e\r\n\r\n\u003cp\u003eDST 1 perforated the interval 3660 m to\r\n3655 m and flowed 1330 STBOPD (211.5","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"318","properties":{"OBJECTID":318,"wlbNpdidWellbore":323,"wlbName":"15/9-2","wlbHistory":"\u003chtml\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 15/9-2 was drilled on the Sleipner\r\nVest Field in the North Sea. The primary objective was to test the "beta\r\nclosure" on the 15/6-3 Sleipner Vest discovery. The target was Middle\r\nJurassic sandstones.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 15/9-2 was spudded with the semi-submersible\r\ninstallation Ross Rig on 12 April 1978 and drilled to TD at 3764 m in Late\r\nTriassic sediments in the Skagerrak Formation. The main problem in operations\r\nwas the discovery of a washout in the well head 18 3/4" ax seal area after\r\nsetting 9 5/8" casing. This was repaired so that drilling could proceed,\r\nbut it was decided not to do the planned DST due to possible leak. Otherwise,\r\noperations proceeded without significant problem. The well was drilled with seawater\r\nand gel down to 644 m and with gel and lignosulphonate from 644 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe Vestland Group, Hugin Formation was\r\nencountered at 3483 m. The Hugin Formation contained gas/condensate down to the\r\nOWC between 3652 and 3654 m based on logs and pressure gradients. Weak shows\r\ncontinued down to 3659 m, 2 meters into top Sleipner Formation. Two spots of\r\ndead oil and fluorescence on limestone/siltstone cuttings at 2788 and 2812 m in\r\nthe upper Shetland Group were the only other shows described in the well.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eA total of 186.3 m core was recovered in\r\n11 cores from the interval 3498 m to 3692 m. RFT fluid samples were taken at\r\n3490 m ((gas, condensate, water), 3535,7 m (gas and condensate), 3601.6 m (gas,\r\ncondensate, water), 3640.4 m (gas, condensate, water), 3641 m (gas, condensate,\r\nwater), 3641.5 m (gas, condensate, water), 3644 m (gas, condensate, water),\r\n3652 m (gas, condensate, water), and 3654 m (water). The condensate gravity in\r\nth","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"319","properties":{"OBJECTID":319,"wlbNpdidWellbore":324,"wlbName":"15/9-3","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell was drilled on the northwestern part\r\nof the Sleipner Vest structure in the Viking Graben of the North Sea. The\r\nobjective was to test hydrocarbons in the “Alpha structure” of the Sleipner\r\nfield. The target was Middle Jurassic sandstones.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 15/9-3 was spudded with\r\nthe semi-submersible installation Ross Rig on 17 December 1978 and drilled to\r\nTD at 3796 m in the Triassic Skagerrak Formation. Many problems were\r\nencountered in the operations. When drilling the 26" interval, the\r\ncirculation was lost several times. Pumping lost circulation material pills and\r\ncement into the formation solved this. The main problem arose when drilling the\r\n8 1/2” interval. \u00A0At 3375 m on top of Upper Jurassic, an abnormally pressured\r\nimpermeable zone was penetrated. Due to a series of technical problems that\r\nfollowed this incident, the well was finally plugged back and sidetracked from\r\n1213 m. Furthermore, the well was drilled in the wintertime and the cold was\r\nquite severe. Because of this, the hydraulic control system for the BOP stack\r\nfroze on one occasion. Functional problems with the BOP pods were experienced,\r\nconsequently, the time and cost estimates, were seriously exceeded. The well\r\nwas drilled with spud mud down to 402 m, with gel/lignosulphonate from 402 m to\r\n2680 m and with gel/lignosulphonate/lignite mud from 2680 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe Middle Jurassic Vestland Group, top\r\nHugin Formation, was encountered at 3498 m. Well 15/9-3 proved very poor\r\nreservoir qualities in these strata and the well was hence not production\r\ntested. A cluster of RFT pressure data points suggested a light hydrocarbon gradient\r\nof 0.11 - 0.25 psi/ft. between 3600 m and 3612 m. Between 3650 m and 3682 m a good\r\n"heavier" hydro","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"320","properties":{"OBJECTID":320,"wlbNpdidWellbore":325,"wlbName":"15/9-4","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 15/9-4 was drilled on in the southeastern\r\npart of the Sleipner Vest area in the Viking Graben of the North Sea. Previously\r\nfour wells had been drilled on the Sleipner Alpha structure in the north. Two\r\nof these showed significant gas-condensate accumulations (15/6-3 and 15/9-1) in\r\nthe middle Jurassic while in the western part of the Alpha structure the sand\r\nhad shaled out (15/9-3). In the northeast, the sand was penetrated below the\r\nhydrocarbon/water contact (15/6-5). The first well drilled on the Beta prospect\r\n(15/9-2) showed a significant gas-condensate column in the middle Jurassic\r\nsand. The primary objective for well 15/9-4 was to test possible hydrocarbons\r\nin Middle Jurassic sandstones in the southeast extending Delta structure. \u00A0\u00A0\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 15/9-4 was spudded with the semi-submersible\r\ninstallation Ross Rig on 4 April 1979 and drilled to TD at 3716 m in the\r\nTriassic Skagerrak Formation. Very few problems were encountered during\r\ndrilling of this well, with the exception of lost circulation in the 26"\r\ninterval. This problem was solved by pumping cement into the formation. The\r\nmain problem arose only after drilling the 8 1/2” interval. The 7" liner\r\nwas run and cemented sucessfully. When pressure was applied in order to test\r\nthe liner lap, the 9 5/8" casing burst. The well was drilled with spud mud\r\ndown to 415 m and with gel/lignosulphonate mud from 402 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eTop of the Middle Jurassic Vestland\r\nGroup, Hugin Formation was penetrated at 3441 m. The section contained\r\nsandstones with good reservoir properties interbedded with some thin shale\r\nbeds. The sandstones were hydrocarbon bearing with a gas-water contact at ca\r\n3570 m, 7 m into the Sleipner Formation. Weak oil shows were described\r\nt","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"321","properties":{"OBJECTID":321,"wlbNpdidWellbore":326,"wlbName":"15/9-5","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 15/9-5 was drilled in the Sleipner\r\nVest area in the Central Graben of the North Sea. The objective was to test\r\nhydrocarbons in Middle Jurassic sandstones in the Beta structure of Sleipner\r\nVest. The well is Reference Well for the Heimdal and Våle formations.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 15/9-5 was spudded with\r\nthe semi-submersible installation Norskald on 19 November 1979 and drilled to\r\nTD at 3946 m in the Triassic Skagerrak Formation. Operations met with many\r\nproblems, but the well objectives were fulfilled in the end. Excessive drag\r\nwhen pulling core barrel out of reservoir was a severe problem, and\r\nconsequently frequent reaming and circulating trips was needed. Having finished\r\nlogging in the 8 1/2” section, and just started testing the BOP stack, one of\r\nthe riser tension sheaves broke and fell down. Also several problems with the\r\nhydraulic BOP control system and the ball joint made nearly 12 days rig repair\r\nnecessary. After this delay the hole required extensive reaming before the 7”\r\nliner could be ran and the final 6” section could be drilled. Testing\r\noperations were hampered and delayed by bad weather and test equipment\r\nbreakdown. The well was drilled with spud mud down to 426 m and with\r\nseawater/lignosulphonate mud from 426 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well proved gas in sandstones of Middle\r\nJurassic age from top Hugin Formation at 3526 m down to a true gas/water\r\ncontact at 3662 m, based on logs and RFT samples. The Sleipner Formation was\r\nencountered at 3693 m. Logs and RFT pressure gradient proved Sleipner water\r\nfilled, and ca 3 bar overpressured compared to the Hugin Formation. Shows were\r\ndescribed on cores all through the hydrocarbon bearing reservoir. Abundant\r\nspots of fluorescence described on cuttings below ca 2000 ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"322","properties":{"OBJECTID":322,"wlbNpdidWellbore":327,"wlbName":"15/9-8","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 15/9-8 was drilled on the Delta\r\nstructure in the southeastern part of the Sleipner West Field in the North Sea.\r\n\u00A0The primary objective was to delineate the hydrocarbon accumulation\r\nencountered in the 15/9-4 well on the same structure, and to get further\r\ninformation about the sand distribution in the area. The primary target was Callovian\r\nsandstones. Paleocene sandstone was the secondary target.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 15/9-8 was spudded with\r\nthe semi-submersible installation Nortrym on 5 March 1981 and drilled to TD at\r\n3730 m in the Triassic Smith Bank Formation. Operations proceeded without\r\nsignificant problems. The well was drilled with seawater and hi-vis pills down to\r\n495 m, with gypsum/polymer mud from 495 m to 2845 m, and with a\r\ngel/lignosulphonate mud from m 2845 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe sandstones in Paleocene were water\r\nbearing. Top of the Callovian sandstone, Hugin Formation, was encountered at\r\n3446 m, while top Sleipner Formation was encountered at 3493 m. Bothe formations\r\nproved to be gas/condensate bearing with a gas-water contact at 3564 m based on\r\npressure gradients and well logs. No shows were recorded outside of the\r\nhydrocarbon bearing Hugin and Sleipner Formation.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eA total of 46.5 m core was recovered in\r\nfour cores from the interval 3448 to 3499 m. Segregated RFT fluid samples were\r\ntaken at 3460 m (gas, condensate and mud filtrate), 3561.5 m (gas, condensate\r\nand mud filtrate), and 3566.5 m (mud filtrate and a smaller quantity of gas).\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was permanently abandoned on 25\r\nMay 1981 as a gas/condensate appraisal well.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eTesting\u003c/span\u003e\u003c/b\u003e\u003cspan lang=","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"323","properties":{"OBJECTID":323,"wlbNpdidWellbore":328,"wlbName":"15/9-9","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 15/9-9, was drilled on the Sleipner\r\nTerrace in the North Sea. The primary objective was to test possible hydrocarbons\r\nin Jurassic sandstones on the 15/9-Gamma structure and to get more information\r\nabout the sand distribution in the area.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 15/9-9 was spudded with the semi-submersible\r\ninstallation Nordraug on 4 May 1981 and drilled to TD at 3044 m in the Early-Middle\r\nPermian Rotliegendes Group. No significant problems were experienced in operation,\r\nlogging or testing of the well. The well was drilled with seawater and pre-hydrated\r\ngel down to 501 m, with gel/lignosulphonate from 501 to 1155 m, with\r\ngypsum/polymer mud from 1155 m to 2540 m, and with gel/lignosulphonate from 2540\r\nm to TD. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe primary objective, the Jurassic, was\r\nthinner than expected and consisted of Late Jurassic Viking Group shales only.\r\nThe well, however, proved gas and condensate in the Heimdal Formation. The\r\nHeimdal Formation was reached at 2322 m. It consisted of sand of fairly good\r\nreservoir properties interbedded with some thin shale beds. The whole sand\r\ninterval was hydrocarbon bearing and no water contact was located. In addition,\r\nthe well proved residual hydrocarbons over the interval 2648 to 2738 m on cores\r\nfrom the Triassic Skagerrak Formation. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eSeven cores were cut. The interval 2648\r\nto 2756 m was cored in six cores with 98 - 100% recovery. A seventh core was\r\ncut from 3032 to 3043.5 m with 96% recovery at TD. RFT segregated samples were\r\ntaken at 2323 m (condensate and mud filtrate) and 2648 m (water and mud\r\nfiltrate, no gas or condensate). Repeated attempts to sample in the interval\r\n2401 to 2414 all failed due to plugging of probe by unconsolidated sand.\u003c/sp","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"324","properties":{"OBJECTID":324,"wlbNpdidWellbore":329,"wlbName":"15/9-11","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 15/11-9 was drilled to appraise the\r\n15/9-9 Sleipner Øst discovery in the south Viking Graben area of the North Sea.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe primary objective was to delineate\r\nthe hydrocarbon accumulation found in the Heimdal Formation of the 15/9-Gamma\r\nstructure. The secondary objective was to test for possible hydrocarbons in\r\nTriassic sandstones.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well is Reference well for the Lista Formation,\r\nthe Meile Member, and the Heimdal Formation\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eAppraisal well 15/9-11 was spudded with\r\nthe semi-submersible installation Ross Rig on 18 September 1981 and drilled to\r\nTD at 2950 m in the Triassic Hegre Group. A total of 99 days including a strike\r\nwas spent on this well. Apart from the strike, which amounted to 22 days of\r\nlost operation, there were no severe problems during drilling and testing\r\noperations. The well was drilled with sea water and bentonite down to 585 m and\r\nwith gel/lignosulphonate/seawater mud from 585 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well proved gas and condensate in\r\nHeimdal formation and verified thereby the results from the 15/9-9 well. The\r\ngas- water contact was found at 2442 m. Hydrocarbons were found also in the Jurassic\r\nHugin Formation sandstones with a gas-water contact at 2825 m. The TD for the\r\nwell was then extended from 2650 to 2950 m. No hydrocarbons were found in\r\nTriassic sandstones \u003c/p\u003e\r\n\r\n\u003cp\u003eEleven cores were cut in the well. Cores\r\n1 and 2 were cut from 2364 to 2379 m in the Lista Formation. Cores 3 to 11 were\r\ncut from 2395 to 2514 m in the Heimdal Formation. The RFT tool was run on wire\r\nline and the pressure data supported communication with the 15/9-9 discovery\r\nwell within the Heimdal Formation, while the Hugin Formation was in a separate\r\npressure regime. Segregated fluid samples were taken at 2387.5 m, in the\r\nHeimdal Formation, and at 2812 and 2825.8to 2826.5 m in the Hugin Formation.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 23\r\nDecember 1981 as a gas/condensate appraisal well.\u003c/p\u003e\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"325","properties":{"OBJECTID":325,"wlbNpdidWellbore":330,"wlbName":"15/9-12","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 15/9-12 was drilled as an appraisal\r\nwell on the saddle area between the Alpha and Beta structures on the Sleipner\r\nVest field in the North Sea. The main objective was to test the Middle Jurassic\r\nsandstones.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAfter setting anchors on 8 November 1981\r\nthe spud was delayed two weeks due to strike by the maritime and drilling crews.\r\n\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 15/9-12 was spudded with\r\nthe semi-submersible installation Nordraug on 22 November 1981 and drilled to\r\nTD at 3740 m in the Middle Jurassic Sleipner Formation. The 36" hole was\r\ndrilled to 195 m but due to bad weather the hole was lost and the well was re-spudded\r\non 26 November. Drilling of the 26" and 17 1/2" holes went forth\r\nwithout significant problems other than tight spots in the lower part of the 17\r\n1/2" hole. When setting the 9 the 5/8" casing shoe at 2755 m 64 m3 mud\r\nwas lost to the formation. The well was drilled with seawater and gel slugs\r\ndown to 501 m, with gel-lignosulphonate mud from 501 m to 1135 m, with lignosulphonate/gypsum/CMC\r\nmud from 1135 m to 2771 m, and with gel-lignosulphonate mud from 2771 to 3740\r\nm.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eA 251 m thick Heimdal Formation was\r\npenetrated from 2374 m to 2625 m. The Heimdal Formation was water bearing\r\nwithout shows. The primary target reservoir Hugin Formation was penetrated at\r\n3510 m and proved to contain gas-condensate with a gas-water contact at 3654\r\naccording to RFT pressure gradients. Weak shows continued on the cores down to\r\n3665 m. The underlying Sleipner Formation was dry without shows. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eA total of 168.8 m core was cut from top\r\nto base of the Hugin Formation. The depth for cores 1 - 9 should be sh","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"326","properties":{"OBJECTID":326,"wlbNpdidWellbore":331,"wlbName":"15/12-2","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 15/12-2 was drilled in order to\r\nevaluate Jurassic formations on a seismic structure located in the eastern part\r\nof block 15/12. The principal objective of the 15/12-2 well was to test the\r\nDogger (Hugin Formation) sandstone, where oil shows had been encountered in the\r\n15/12-1 well. A secondary object was a possible sand in the Paleocene. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 15/12-2 was spudded with the\r\nsemi-submersible installation Ross Rig on 7 January 1976 and drilled to TD at\r\n2924 m in Late Permian Zechstein anhydrite. The well was drilled with a\r\nlignosulphonate mud system. \u003c/p\u003e\r\n\r\n\u003cp\u003eNo sand was found in the Paleocene. The\r\nHugin Formation sandstone was found 304 meters higher than in the 15/12-1 well.\r\nThe sandstone proved to have very good reservoir qualities, but was completely\r\nwater bearing. There were sandstone stringers in the lower part of the Heather\r\nFormation. The Hugin Formation sand was cored from 2823 m to 2835.4 m, with no\r\nshow. No fluid sampling was attempted in the well.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned as a\r\ndry well on 27 February 1976.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was performed\u003c/p\u003e\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"327","properties":{"OBJECTID":327,"wlbNpdidWellbore":332,"wlbName":"16/1-2","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 16/1-2 is located on the eastern\r\nside of the Gudrun Terrace, towards the Utsira High in the North Sea. The well\r\nwas designed to test all potential reservoirs through the Permian on a closure\r\non a large, rotated fault-block. Primary objectives were Jurassic sandstones\r\nand secondary objectives were Paleocene sandstones.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 16/1-2 was spudded with the\r\nsemi-submersible installation Ross Rig on 4 July 1976 and drilled to TD at 2919\r\nm in granite basement. Loss of circulation in high-porosity Zechstein\r\ncarbonates was the only significant problem encountered during the drilling of\r\n16/1-2. Initial drilling from the sea floor to 1286 meters was with sea water\r\nand gel. Below this depth a fresh water and lignosulphonate mud system was\r\nused.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well penetrated several sands in the Tertiary\r\nincluding the Utsira, Skade, and Grid formations. The Heimdal Formation was\r\nencountered at 2098 m with a 10 m zone of strong oil shows. The zone was\r\nhowever judged by log analysis to be water-productive and the shows not of\r\nsufficient quality to warrant testing. Triassic sandstones were originally interpreted to be water-filled. Later reinterpretation have confirmed the presence of oil in the Triassic interval. There were no shows from either the Zechstein or the Rotliegendes\r\nsandstone.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo cores were cut and no wire line fluid samples\r\nwere taken.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was permanently abandoned on 7\r\nAugust 1976 as a dry well with shows.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eTesting\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo drill stem test was performed.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\r\n\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"328","properties":{"OBJECTID":328,"wlbNpdidWellbore":333,"wlbName":"30/6-16","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 30/6-16 was drilled on the\r\nTheta structure, immediately northwest of the main Oseberg Alpha North\r\nstructure. The main objective of the well was to prove hydrocarbons in the\r\nStatfjord Formation. Planned TD was ca 3150 m or ca 225 m into the Statfjord\r\nFormation.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 30/6-16 was spudded with the\r\nsemi-submersible installation Treasure scout on 9 November 1984 and drilled to\r\nTD at 3300 m in the Triassic Hegre Group. Drilling proceeded without\r\nsignificant problems. The well was drilled with spud mud down to 613 m and with\r\nKCl/polymer mud from 613 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eGood oil shows were reported on dolomite\r\nand limestone beds and stringers from 1993 to 2333 m in the Rogaland and\r\nShetland groups. From 2605 to 2853 (Shetland Group) good oil shows were\r\nrecorded in sandstones and siltstones as well as in limestones. The Brent Group\r\nwas encountered at 2856 m and consisted of 12 m Etive Formation only. The Etive\r\nFormation was found to be oil bearing over the entire interval. The net pay was\r\n6.3 m with average log porosity of 19.1%. Also the 26 m thick Cook Formation\r\nwith top at 2920 m was oil bearing all through. Net pay here was 12.6 m with\r\naverage log porosity of 19.0%. No oil/water contacts could be established. The\r\nStatfjord Formation had weak shows in the top 10 m, but was found to be water\r\nbearing. RFT pressure recordings and sampling were recorded in 5 runs.\u00A0\r\nDifferent pressure regimes were proved for the Etive Formation, the Cook\r\nFormation and the Statfjord Group.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eFour cores were cut in the Etive and\r\nDrake Formations (2856 - 2909 m), two in the Cook and Amundsen/Burton\r\nformations (2923 - 2949 m) and one in the Statfjord Formation (2982 - 2990 m)","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"329","properties":{"OBJECTID":329,"wlbNpdidWellbore":334,"wlbName":"16/3-2","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 16/3-2 was drilled 40 m east of\r\n16/3-1 on the Utsira High in the North Sea. The objectives were to investigate\r\nPaleocene sand pinch out, the weathered top of the Cretaceous chalk and\r\nJurassic sandstone. The 16/3-2 well is a replacement for well 16/3-1, which was\r\njunked for technical reasons. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 16/3-1 was spudded with the\r\nsemi-submersible installation Polyglomar Driller on 11 February 1976 and\r\ndrilled to TD at 2019 m in granite basement. No significant problems were\r\nreported from the operations. The well was drilled with spud mud (gel and lime)\r\nand pre-hydrated bentonite down to 440 m, and with lignosulphonate mud from 440\r\nm to TD. Around the well there was a 3 m deep and 15 m wide crater. Gas was\r\nobserved leaking from 2 main openings and 1 minor. The gas flow from one of the\r\nmajor openings was about 400 l/hour. The gas was practically pure methane\r\n(99.98%), probably coming from layers near the surface.\u003c/p\u003e\r\n\r\n\u003cp\u003eThere were no sands in Paleocene and the Cretaceous\r\nchalk was tight. A 20 m thick immature Draupne shale was encountered at 1955 m.\r\nThe well then encountered a 31 m thick late Jurassic sandstone from 1975 m to\r\n2006 m. Below this sandstone was a 9 m thick layer of weathered basement\r\noverlying the solid granite. The well proved to be water wet all through, and\r\nno shows were recorded.\u003c/p\u003e\r\n\r\n\u003cp\u003eThree cores were cut. Core 1 gave no\r\nrecovery, while core recovered 3.5 m core from the interval 1998 m to 2000.6 m\r\nin the Late Jurassic sand. Core no 3 was cut from 2017.5 m to 2019 m in\r\nbasement rock. No fluid sample was taken in the well.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 8\r\nMarch 1976 as a dry well.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was performed\u003c/p\u003e\r\n\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"330","properties":{"OBJECTID":330,"wlbNpdidWellbore":335,"wlbName":"16/8-1","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was located to test a\r\nthrust-faulted structure in a NE-SW trending sub-basin to the southeast of the\r\nUtsira High. The primary objective was the basal Late Jurassic sand. This sand\r\nwas estimated to have an approximate gross thickness of 71 metres.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 16/8-1 was spudded with the\r\nsemi-submersible installation Nordskald on 25 September 1976 and drilled to TD\r\nat 2301 m in the Triassic Smith Bank Formation. The well was drilled with\r\nseawater and gel down to 172 m and with Drispac and seawater from 172 m to TD. \u003c/p\u003e\r\n\r\n\u003cp\u003eNo reservoir sands were encountered in\r\neither the Paleocene or the Triassic. From 1769 m to 1820 m in the Late\r\nCretaceous Tor and Hod Formations chalks with calculated porosities from 17% to\r\n34% were encountered. At 2073 the well penetrated a gross thickness of 43 m of\r\nLate Jurassic Intra Draupne sand. This sand was of high porosity but water\r\nbearing. No evidence of hydrocarbons was encountered while drilling, and log\r\nanalysis confirmed all intervals with significant porosity to be water bearing.\r\nCanned samples for source rock/maturity analysis by Robertson Research were\r\ncollected every 100 m from 1000 m and every 30 m from 2000 m to TD. This study\r\nshows that the penetrated sections are immature. Samples from the Draupne\r\nFormation show good source characteristics with TOC from 3% to 7% and one\r\nextract from this section contained minor amounts of probably locally generated\r\nhydrocarbons. No conventional cores were cut and no fluid samples taken. The\r\nwell was plugged and abandoned as a dry hole on 29 October 1976. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was performed\u003c/p\u003e\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"331","properties":{"OBJECTID":331,"wlbNpdidWellbore":336,"wlbName":"16/11-2","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThe Anchovy (16/11-2) well was drilled on\r\na semi-domal structure, about 5 miles long and 4 miles wide situated in the\r\nDanish-Norwegian Basin. It was estimated that at Paleocene depth there would be\r\n12 square miles of closure with 150 m vertical relief and at Jurassic depth, 9\r\nsquare miles of closure with 370 m vertical relief. The principal objective\r\nhorizons were the Jurassic and Paleocene sands.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 16/11-2 was spudded with the\r\nsemi-submersible installation Ocean Viking and drilled to TD at 2378 m in Late\r\nPermian Zechstein salt. \u003c/p\u003e\r\n\r\n\u003cp\u003eNo Paleocene sands were encountered. As\r\nexpected the Danian Chalk section was missing in the well. The Upper Cretaceous\r\nLimestone was tight with no shows. The Jurassic sand top was encountered at\r\n2202 m with the main sand development beginning at 2207 m. The net sand\r\nthickness was 35 m, but on testing was found to be tight and unproductive. The\r\ntotal Jurassic section was about 244 m thinner than anticipated. The Triassic was\r\nmissing. An 11.5 m Dolomite section was developed from 2250 m to 2261.5 m at\r\nthe top of the Permian succession. This was also tested, but found to be tight\r\nand unproductive. Thus the well was terminated in the Zechstein higher than\r\nplanned. Except for the reduced Jurassic sequence and absence of Triassic\r\nsediments causing the higher position of the Zechstein, the structure and\r\nstratigraphy were as predicted in the prognosis. Geochemical analyses of shales\r\nfrom the Late Jurassic Tau Formation proved excellent source potential, but the\r\nkerogen is immature to marginally mature in the well location. No cores were\r\ncut. The well was permanently abandoned as a dry well on 23 July 1973.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eTwo intervals in the Sandnes Formation\r\nwere perforated and tested, 2261 m to 2251 m and 2242 m to 2231 m. Both\r\nintervals were found tight and unproductive and no hydrocarbons were produced\r\nduring the tests.\u003c/p\u003e\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"332","properties":{"OBJECTID":332,"wlbNpdidWellbore":337,"wlbName":"17/9-1","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 17/9-1 is located in the Åsta Graben\r\nin the North Sea, ca 30 km north of the 17/12-1R Bream Discovery well. The\r\nprimary objective was to evaluate sands at the base of the Jurassic sequence.\r\nThe structure is not associated with mobile salt, which is the case for the\r\nBream Discovery.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well is Reference Well for the\r\nFjerritslev Formation.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 17/9-1 was spudded with the\r\ndrill ship Glomar Grand Isle on 16 September 1973. Initial drilling from the\r\nsea floor to 423 m was with seawater and gel. From the 20-inch casing shoe at\r\n409 m to TD a fresh water Spersene XP-20 mud system was used. The well was\r\ndrilled to 2816 m in Early Jurassic sediments when drilling operations were\r\nsuspended due to a severe storm. During this storm on November 6, the riser was\r\ndropped from the drill ship. During subsequent efforts the riser was broken\r\nleaving a riser stub approximately 13 m above the ocean floor. Due to this logs\r\nwere not run below 2616 m. \u003c/p\u003e\r\n\r\n\u003cp\u003eNo good reservoir sequence was\r\nencountered in the well. Some porosity was noted in cores from the formation\r\nunderlying the Sandnes Formation. No shows were recorded during drilling, and\r\nthe lack of hydrocarbons in 17/9-1 was confirmed by logs run in the re-entry.\r\nOrganic geochemical analyses showed excellent source rock quality in the Late\r\nJurassic interval from 2120 m to 2210 m with TOC in the range 2.5 % to 9.4 %\r\nand hydrogen index from 130 to 490 mg HC/g rock. The well is immature (%Ro\r\n<0.5) all through. Two conventional cores were cut in the intervals 2268 m\r\nto 2276.8 m and 2286 m to 2294.8 m. No fluid samples were taken.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was secured and temporary\r\nsuspended on December 23 as a dry hole.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was performed.\u003c/p\u003e\r\n\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"333","properties":{"OBJECTID":333,"wlbNpdidWellbore":338,"wlbName":"17/11-2","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThe prospect lay in the Egersund Basin\r\nWest of Phillips' marginal Bream and Brisling discoveries. Well 17/11-2 was\r\nlocated to penetrate Middle Jurassic/Triassic sands on the west flank of a\r\nNNE-SSW piercement salt wall. A pair of prominent west-dipping growth faults\r\nmarks the western edge of the salt wall. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe well is reference well for the Åsgard\r\nFormation and Ran sandstone units.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 17/11-2 was spudded with the\r\nsemi-submersible installation Chris Chenery on 12 April 1976 and drilled to TD\r\nat 2644 m in the Triassic sediments. The well was drilled without significant\r\nproblems with bentonite/seawater spud mud down to 436 m and with Lime/PAC\r\n(Drispac)/seawater from 436 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eTop chalk was picked at 1323 m. Dipmeter\r\nevidence indicated several faults within the Early Cretaceous sequence, at 2025\r\nm, 2244 m and 2382 m. Apart from minor gas shows while drilling in the Early\r\nCretaceous/Late Jurassic shales, no hydrocarbon indications (shows and logs) were\r\nseen in the well. Dark grey to black carbonaceous Kimmeridgian shales were\r\npenetrated from 2495 m to 2521 m. The top of the target ?Triassic sandstone at\r\n2521 m was marked by a sudden increase in penetration rate and sand grains in\r\nthe cuttings. A total of 35 m net sand with 17 - 30 % porosity was evaluated,\r\nthe thickest single sand unit was 7.5 m. One conventional core was cut from\r\n2532.7m to 2540.4 m. No fluid samples were taken.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 24\r\nMarch 1969 as dry hole.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was performed.\u003c/p\u003e\r\n\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"334","properties":{"OBJECTID":334,"wlbNpdidWellbore":339,"wlbName":"17/12-1","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eExploration well 17/12-1 is located on\r\nthe northern margin of the Egersund Basin in the North Sea, towards the Åsta\r\nGraben. Its primary target was Jurassic sands (Bream prospect) with estimated\r\ntop at 2161 m (7090 feet) and with 61 m (200 feet) thickness. Sand developments\r\nwithin the Early Cretaceous and Triassic sections were regarded as secondary\r\nobjectives. Planned TD was 8 m (25 feet) into the Zechstein salt.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 17/12-1 was spudded with the 3 leg\r\njack-up installation Mærsk Explorer on 27 October 1971 and drilled to TD at 458\r\nm in the 26" section where it was suspended on 1 November for later\r\nre-entry with a different rig, Ocean Viking.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was performed.\u003c/p\u003e\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"335","properties":{"OBJECTID":335,"wlbNpdidWellbore":340,"wlbName":"17/12-2","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 17/12-2 is located on the\r\nnorthwestern margin of the Egersund Basin in the North Sea, ca 14 km southwest\r\nof the 17/12-1R Discovery. The primary objective was to test Middle Jurassic\r\nand/or Triassic sands. Both had been found present in the 17/12-1R well where\r\nthe Middle Jurassic sand was oil-bearing (Bream Discovery). The Triassic sands\r\ncould be oil-bearing, especially if overlain by Jurassic shale. A secondary\r\nobjective was seen in the Late Cretaceous limestones. Planned TD was at 3658 m\r\n(12000 ft) or 100 m into Zechstein salt.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 17/12-2 was spudded with\r\nOcean Viking on 31 August 1973 and drilled to TD at 2334 m in Devonian sand. \u003c/p\u003e\r\n\r\n\u003cp\u003eNo shows were present in the Late\r\nCretaceous Limestone. An oil-bearing Jurassic sand 13 m thick (7 m net pay) was\r\nencountered at 2157 m. The Triassic was absent and the Jurassic Sandnes and\r\nBryne Formations rested directly on a 50 m thick layer of Permian salt at 2243\r\nm. Below the salt was a 7 m thick Rotliegendes sequence. Sandstone of possible\r\nDevonian age was encountered at 2300 m. This remnant Paleozoic feature caused\r\nthe well to be terminated higher than originally anticipated.\u003c/p\u003e\r\n\r\n\u003cp\u003eOne conventional core was cut at TD from\r\n2330.8 m to 2333.9 m. No wire line fluid samples were taken.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 9\r\nOctober 1973 as an oil Discovery.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eTwo drill stem tests were carried out.\r\nDST1 from 2166 m to 2169 m produced 16 m3 water cushion and 1 m3 oil. After the\r\nfinal flow period water cushion and formation fluid was reversed out. DST2 from\r\n2157 m to 2162 m produced at maximum 366 m3 oil and 31800 m3 gas / day. Gas-oil\r\nratio was 87 m3/m3 and oil gravity was 27.9 °API. \u003c/p\u003e\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"336","properties":{"OBJECTID":336,"wlbNpdidWellbore":341,"wlbName":"17/12-3","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 17/12-3 is located on the northern\r\nmargin of the Egersund Basin in the North Sea, ca 3 km west of the 17/12-1R\r\nBream Discovery well. The Bream structure is a domal (salt-induced) anticline.\r\nThe pay zone is the Middle Jurassic sands at a sub-sea depth of 2377 m (7800\r\nfeet). The 17/12-1R well was drilled on the crest of the Bream structure. Here\r\nLate Jurassic black marine shales with excellent source rock potential overlie\r\na 156 m thick Early - Middle Jurassic sequence of interbedded sands and shales\r\nin which net sand thickness totals 38 m. Two 8 m thick sands near the top of\r\nthe Middle Jurassic section tested oil. The Upper sand was oil saturated and\r\nthe lower sand contained an oil/water contact between 2337.2 m and 2344 m (2310.4\r\nm and 2317 m MSL). Two overlying sands, however, contained only water, which\r\nindicates that individual sands possess independent hydrodynamic\r\ncharacteristics and, therefore, probably are lenticular and laterally\r\ndiscontinuous. It was expected that on the flank of the structure potential\r\nreservoir sands would be thicker, and additional sands would be encountered.\u00A0 \u003c/p\u003e\r\n\r\n\u003cp\u003eHence, primary objective was Middle\r\nJurassic sands. Estimated top and thickness of the sand was 2313 m (7590 ft)\r\nand 91 m (300 ft), respectively. Planned TD was at 2591 m (8500 ft), 120 m into\r\nTriassic sediments\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 17/12-3 was spudded with the\r\nsemi-submersible installation Nortrym on 12 December 1979. Due to technical\r\nproblems it was re-spudded 19 December. The well was then drilled without\r\nsignificant problems to TD at 2730 m in m in the Triassic Skagerrak Formation. \u003c/p\u003e\r\n\r\n\u003cp\u003eTop Cretaceous (Tor Formation) came inn\r\nat 817 m, 28 m deeper than prognosed. The target Middle Jurassic reservoir sand\r\n(Sandnes and Bryne Formations) came in at 2370 m (2345 m MSL), which was 57 m\r\ndeep to prognosis and ca 30 m MSL deeper than the OWC indicated by the DST's in\r\n17/12-1R. No significant shows were encountered in t","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"337","properties":{"OBJECTID":337,"wlbNpdidWellbore":342,"wlbName":"18/10-1","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 18/10-1 is located in the Egersund Basin in the North Sea, ca 16 km southeast of the 17/12-1R Bream Discovery. It was\r\ndesigned to test a seismic structure on the same trend as the Bream discovery.\r\nThe primary target was to test possible hydrocarbon accumulation in Jurassic\r\nsandstones on. Planned TD is about 150 to 200 m below Jurassic sandstone in a\r\nshaly-sandy sequence of Early Jurassic or top of Triassic.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 18/10-1 was spudded with the\r\nsemi-submersible installation Dyvi Alpha on 19 October 1979 and drilled to TD\r\nat 2800 m in the Triassic Skagerrak Formation. \u003c/p\u003e\r\n\r\n\u003cp\u003eA thick Late Jurassic shale sequence with\r\nlimestone stringers was penetrated before reaching the target Middle Jurassic\r\nsands. The sands (Sandnes and Bryne Formations) were encountered at 2405 m,\r\nclose to prognosis. The reservoir consisted of two zones separated by a thin\r\nshale barrier between 2427 and 2433 m. Based on FMT and DST pressure\r\nmeasurements the upper zone appeared slightly overpressured relative to the\r\nlower, suggesting a compartmentalized reservoir. The reservoirs were found\r\nhydrocarbon bearing and an OWC was found at 2437 m in the lower zone. The\r\nlithology below the target reservoir section, from 2483 m to TD, was\r\npredominantly sandstone, fine in the upper part, becoming medium to coarse\r\ndownwards. Frequent thin interbeds of shale and marl, occasionally also thin\r\nstringers of limestone were encountered. The sequence was entirely water\r\nbearing. Weak direct fluorescence and cut appears at 2420 m, becoming very good\r\nin the intervals 2423 m to 2430 m and 2433 m to 2440 m, then the shows get\r\nweaker and disappear below 2444 m. \u003c/p\u003e\r\n\r\n\u003cp\u003eOrganic geochemical analyses showed an\r\nimmature well all through (%Ro = 0.5 at TD). TOC in the Late Jurassic shale\r\nincreased gradually from ca 0.8% at top Jurassic to ca 1 % at 2200 m. A peak\r\nTOC is reached in the Tau Formation with 4.5 % TOC in cuttings and 6.9 % in a\r\nsidewall core. The hydroge","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"338","properties":{"OBJECTID":338,"wlbNpdidWellbore":343,"wlbName":"18/11-1","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 18/11-1 is located on the Stavanger\r\nPlatform, ca 25 km north of the Yme Field in the North Sea. The primary\r\nobjective was to test possible hydrocarbon accumulation in Middle Jurassic\r\nsandstones in a seismic structure interpreted on the same trend as the 17/12-1R\r\nBream Discovery. Secondary objectives were possible Triassic or Rotliegendes\r\nsandstones in a faulted triangular block tilted southwest. Planned TD was 150\r\n-200 m below the primary target, prognosed at 2365 m.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well is Reference Well for the\r\nSandnes Formation.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 18/11-1 was spudded with the\r\nsemi-submersible installation Deepsea Driller on 17 February 1974 and drilled\r\nto TD at 2086 m in Pre-Devonian Basement rocks.\u003c/p\u003e\r\n\r\n\u003cp\u003eLate Cretaceous limestones from 498 m to\r\n985 m had excellent reservoir properties. Limestones below this level became\r\nharder; more compacted, and had poor reservoir properties. The well penetrated\r\ntop Sandnes Formation at 1878 m with fine, argillaceous cemented, well sorted sandstone\r\ndown to 1919 m, and a Bryne Formation sequence with fine to coarse, angular\r\ngrained, sandstones with variegated shale from 1964 m to 2060 m. The Jurassic\r\nsands rested directly on basement at 2060 m. No noticeable shows were recorded\r\nin the well. Organic geochemical analysis proved a thermally immature well all\r\nthrough down to basement (%Ro < 0.36). Good source potential (TOC in the\r\nrange 1.3 % to 6 % and Hydrogen Index from 30 to 230 mg HC/g rock was seen in a\r\nca 80 m thick Kimmeridgian shale sequence from 1735 m. High TOC in the range\r\n1.3 % up to 6.9 % was seen also below 1919 m in Callovian claystones, but\r\nHydrogen Index in the range 30 - 180 mg HC/g rock suggested a more inertinitic,\r\ngas prone kerogen in this sequence.\u00A0 \u003c/p\u003e\r\n\r\n\u003cp\u003eOne conventional core was cut at TD from\r\n2082 m to 2086 m. No fluid samples were taken.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 31\r\nMarch 1974 as dry hole.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"339","properties":{"OBJECTID":339,"wlbNpdidWellbore":344,"wlbName":"24/9-1","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 24/9-1 is located in the\r\nVana Sub-basin in the Southern Viking Graben, about 11 km east of the border to\r\nBritish sector. The well was drilled to test a large, dip-closed structure\r\nlocated in the centre of the Viking Graben. The target was Late Jurassic\r\nsandstones. Two sandstone intervals were expected in the well, with a possible\r\ngross thickness of about 250-300 m. The prognosis was based on a correlation\r\nwith the UK wells 16/7-1, 16/8-1 and the Norwegian well 15/3-1 which are\r\nsituated in a similar position as 24/9-1 relative to the eastern boundary fault\r\nof the Viking Graben. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe well is Reference Well for the\r\nSvarte, Tryggvason, Kyrre, and Jorsalfare Formations.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 24/9-1 was spudded with the\r\nsemi-submersible installation Ross Rig on 29 February 1976 and drilled to TD at\r\n4907 m in the Late Jurassic Heather Formation. Below the 20" casing at\r\n758.3 m the Formations drilled contained abundant sand and was drilled\r\nextremely fast. This created problems as the solids removal system on the rig\r\nwas incapable of removing the sand as fast as it was drilled. In addition the\r\npolymer mud system chosen did not provide sufficient fluid loss control in the\r\nporous formation and large amounts of fluids were lost to the formation. From\r\nca 2440 m to TD at 2752 m in the 17 1/2" hole low penetration rates was a\r\nproblem. Of 126 rig days 20 % was counted as lost time, but the total time\r\nspent on the well was still less than the originally estimated 139 days. Problems\r\nrelated to tight/sloughing hole and down hole tool failure accounted for\r\nroughly half of the lost time. The well was drilled with seawater down to 256\r\nm, with lime / lignosulphonate from 256 m to 3983 m, with Dextrid /\r\nLignosulphonate from 3983 m to 4613 m, and with lime / lignosulphonate from\r\n4613 m to TD. \u003c/p\u003e\r\n\r\n\u003cp\u003eTertiary sandstones were encountered in\r\nthe Grid Formation (1131 m to 1420 m), The Heimdal Formation (2202 m to 2497\r","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"340","properties":{"OBJECTID":340,"wlbNpdidWellbore":345,"wlbName":"24/9-2","wlbHistory":"\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 24/9-2 was drilled in the Vana\r\nSub-basin in the Southern Viking Graben of the North Sea. The well was located\r\nto test Danian and Early Paleocene sands. Dip closure at this level was\r\nenhanced by a seismic anomaly of a "build-up" shape within the\r\nMiddle-Late Paleocene Heimdal sands.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 24/9-2 was spudded with the\r\nsemi-submersible installation Borgny Dolphin on 13 June 1977 and drilled to TD\r\nat 2743 m in the Late Cretaceous Tor Formation. A total of 9.8 days was lost on\r\nvarious mechanical hole problems during. The well was drilled with seawater and\r\ngel down to 1554 m and with lignosulphonate / CMC / gel / seawater from 1554 m\r\nto TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well penetrated a gross interval of\r\n439 m of Paleocene sands. No sands were found in the Danian, which was of a\r\nmarl and limestone lithology. Hydrocarbons in commercial quantities were not\r\nencountered. While drilling the gas detector showed two slight increases, one\r\nwithin the Late Paleocene (a thin intra-Sele Formation sandstone) and one\r\nwithin the Early Paleocene Sand. Fluorescence was observed in the samples from\r\nthe Late Paleocene Sand. Log analysis proved a 3-meter hydrocarbon bearing interval\r\nin the Late Paleocene sand between 2101.5 and 2104.5 metres, and sidewall cores\r\nproved the presence of oil in this interval.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo cores were cut, and no wire line fluid\r\nsamples were taken.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was permanently abandoned on 22\r\nJuly 1977 as a well with shows.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eTesting\u003c/span\u003e\u003c/b\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo drill stem test was performed.\u003c/span\u003e\u003c/p\u003e\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"341","properties":{"OBJECTID":341,"wlbNpdidWellbore":346,"wlbName":"24/9-3","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eExploration well 24/9-3 was drilled by\r\nConoco for the Conoco/Statoil/Norsk Hydro/Hudbay PL 039 partnership. The well\r\nlies in the west-central part of block 24/9, close to the Norway/UK median\r\nline. The location was chosen to test an apparent sand build-up, observable on\r\nseismic lines, in the Lower Tertiary part of the section. The sand build-up was\r\nthought to correspond to the Lower Eocene Frigg Sand Formation, which forms the\r\nreservoir in the Frigg Field.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 24/9-3 was spudded with the\r\nsemi-submersible installation SEDCO 704 on 28 January 1981 and drilled to TD at\r\n3051 m in the Late Cretaceous Jorsalfare Formation. The duration of the well\r\nwas 81 days, 20 of which were spent testing. A 36" hole was drilled to\r\n207.6 m / 681 ft and 30" casing set to same depth. A 17 1/2" pilot\r\nhole was drilled to 518.2 m, logged, and then opened to 26". 20" x-56\r\ncasing was set at 503.2 m. A 17 1/2" hole was drilled to 1600.2 m, logged,\r\nand 13 3/8" N-80 casing was set at 1587.1 m. A 12 1/4" hole was\r\ndrilled and cored to 2049.8 m, logged, and 9 5/8" N-80 casing was set then\r\ndrilled to TD and logged. The well was drilled with spud mud to 518 m, with\r\nDextrid/gel from 518 m to 853 m, with gel/lime from 853 m to 1067 m, with\r\nseawater/gel/Dextrid from 1067 m to 1600 m, and with seawater/lime/Dextrid mud\r\nfrom 1600 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe Lower Eocene sands (Frigg Formation)\r\nwere encountered 141 m high to prognosis at 1739 m. This shows that the sands\r\ncorrespond to a higher and less distinct build-up on the seismic. The build-up\r\noriginally mapped corresponded to the Paleocene Tuff level and contained shales\r\nand water-wet Paleocene Sands. A gross interval of 92 m of Early Eocene Sands\r\nwas penetrated. The uppermost 70 m, from 1739 m, were hydrocarbon bearing down\r\nto an OWC at 1809 m, while the lowermost 22 m (1809-1831m) were water bearing.\r\nPatchy oil shows were observed down to 1870 m, no sho","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"342","properties":{"OBJECTID":342,"wlbNpdidWellbore":347,"wlbName":"24/12-1","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 24/12-1 is located on the Gudrun\r\nTerrace ca 15 km east of the border to British sector. The purpose of the well\r\nwas to evaluate a seismic closure, named Gamma, in the southern part of the\r\nBlock. The main target was the Middle Jurassic sands. Well 24/12-1 was the\r\nfirst of two phases in drilling the borehole, and this first phase was planned\r\nto reach the Early Cretaceous only. The main target was planned to be reached\r\nin a later re-entry with a different rig than was available at the time when\r\nthe well was scheduled.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well is Type Well for the Skade\r\nFormation and Reference Well for the Grid Formation.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 24/12-1 was spudded with the\r\nsemi-submersible installation Ross Rig on 16 January 1978. At the time when the\r\nwell was to be spudded, Statoil did not have available a rig equipped with a\r\n15000 psi BOP stack and associated equipment. The well was therefore spudded\r\nwith Ross Rig, which was equipped with a 10000 psi BOP. Ross Rig drilled the\r\nwell down to 3966 m in the Early Cretaceous Sola Formation. The 9 5/8"\r\ncasing was set and the well was temporarily plugged and abandoned. The problems\r\nexperienced during PHASE I were primarily related to weather (anchor chain\r\nbreakage and WOW), BOP-stack, and items lost into the hole and the sea. The\r\nwell was drilled with seawater and gel from down to 771 m, with lignosulphonate\r\nmud from 771 m to 2874 m, and with lignosulphonate/lignite/CMC from 7874 m to\r\nTD. From 2870 m 1 % to 8% oil was added to the mud.\u003c/p\u003e\r\n\r\n\u003cp\u003eTertiary sandstone intervals were\r\nencountered in the Utsira Formation (497 m to 730 m), the Skade Formation (825\r\nm to 1007 m), the Grid Formation (1502 m to 1660 m), and in the Paleocene\r\nHeimdal Formation (2326 m to 2700 m). No shows were encountered during drilling,\r\nbut post-well organic geochemical analyses showed one cuttings sample from 2860\r\nm to 2890 m to contain significant amounts of light hydrocarbons combined with\r\na comparati","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"343","properties":{"OBJECTID":343,"wlbNpdidWellbore":348,"wlbName":"24/12-2","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 24/12-2 is located in the Vana Sub-basin in the Southern Viking Graben, about 11 km east of the border to British\r\nsector. The well was drilled on structure (Alpha) in the northeastern part of\r\nthe block. Target was Late Jurassic sandstones.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well is Reference well for the Sola\r\nand Grid Formations\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 24/12-2 was spudded with the\r\nsemi-submersible installation Dyvi Delta on 23 June 1981 and drilled to TD at\r\n5100 m in the Late Jurassic Heather Formation. Operations on both 36" and\r\n26" sections went smooth. During drilling of the 17 1/2" section the\r\ndrill pipe broke off at 2044 m. This was recovered and drilling continued to\r\n2445 m. One stand was left in the hole at this depth and fishing was unsuccessful.\r\nBoth fish and open hole were cemented up to 2160 and the well was sidetracked\r\nfrom 2220 m. After setting the 13 3/8" at 2886 m casing the Kelly bushing\r\nelevation was changed from 32 m to 30 m. The 8 1/2" hole was drilled to\r\n4306 m when a 21-day strike occurred. The well was drilled with seawater and\r\ngel down to 1005 m, with gypsum / lime / polymer from 1005 m to 2866 m, and\r\nwith a Spersene / XP-20 / Resinex mud from 2886 m to TD. \u003c/p\u003e\r\n\r\n\u003cp\u003eTertiary sandstones were encountered in\r\nthe Grid Formation (1282 m to 1397 m), the Heimdal Formation (2202 m to 2407\r\nm), and the Ty Formation (2567 m to 2617 m). The main target Late Jurassic\r\nsandstones were found (Intra Heather Sandstone Formation) in the intervals 4739\r\nm to 4749 m and 4955 m to 4978 m. These sands had poor reservoir properties.\r\nOil shows were recorded in the Heimdal Formation. Ca 380 m of Draupne Formation\r\nwas penetrated by this well. The dark shales in this formation had TOC\r\ntypically in the range 4 % to 7 %, but with relatively low Hydrogen Index (50 to\r\n110 mg/g HC). The Kerogen in the shales appeared to be mostly type III with\r\nsome Type II towards the top. Measured vitrinite reflectance varies somewhat\r\nbe","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"344","properties":{"OBJECTID":344,"wlbNpdidWellbore":349,"wlbName":"25/1-3","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 25/1-3 was drilled to appraise the eastward\r\nextension of the 25/1-1 Frigg Discovery on the Frigg Ridge in the North Sea. The\r\nprimary objective was to test the Eocene sandstones that were gas bearing in\r\nwell 25/1-1.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 25/1-3 was spudded with\r\nthe semi-submersible installation Pentagone 81 on 14 November 1971 and drilled\r\nto TD at 2872 m in the Late Cretaceous \u00A0Shetland Group. The well was drilled\r\nwith seawater down to 405 m and with a seawater/LFC mud from 405 m to TD. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe target Eocene sandstones (Frigg\r\nFormation) was penetrated at 1952 m. The gross thickness was 217 m and the N/G\r\nwas 0.82 with porosities ranging from 28 to 33%. It was gas bearing down to the\r\nGOC at 1973 m and oil bearing down to the OWC at 1982.5 m. Good oil shows on\r\ncores were recorded throughout the hydrocarbon-bearing reservoir. Weaker oil\r\nshows on cores were described ("fluo but salty taste") below the OWC.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThree cores were cut from 1951 to 2005 m\r\nin the Frigg reservoir. Total recovery for these three cores was 42.25 m (78.2%\r\nrecovery). A fourth core was cut from 2563 to 2568 m with 50% recovery. FIT\r\nfluid samples were attempted at 2550.5 m and 2576.3 m but only mud and filtrate\r\nwas recovered.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was permanently abandoned on 27\r\nJanuary 1972 as an oil and gas appraisal well\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eTesting\u003c/span\u003e\u003c/b\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eSix drill stem tests were conducted. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eDST 1, 2 and 3 tested the interval 1985\r\nto 1987 m. All three tests produced water.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"345","properties":{"OBJECTID":345,"wlbNpdidWellbore":350,"wlbName":"25/1-4","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eExploration well 25/1-4 was located on a\r\nlower Eocene structure straddling the 25/1 and 30/10 blocks limit, north-east\r\nof the main Frigg Field. It was drilled to explore additional gas reserves in\r\nthe Frigg area. A "Bright spot" phenomenon interpreted as a gas/oil\r\nor water table is clearly visible on all the seismic sections crossing the\r\nstructure. Possible Danian and Maastrichtian reservoirs were considered\r\nsecondary objectives.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eáWell 25/1-4 was spudded with the\r\nsemi-submersible installation Deepsea Driller on 1 April 1974 and drilled to TD\r\nat 2795 m in Maastrichtian marls. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe top of the Eocene reservoir (Frigg\r\nFormation) at 1967.8 was detected by C1 traces (maximum 3%). Based on shows on\r\ncores and electrical logs gas/oil and oil/water contacts were found at 2005.6 m\r\nand 2009 m, respectively. The contacts were not the same as on the Frigg Field,\r\nimplying that this discovery was not in communication with the main Frigg\r\nField. Background gas was weak to nil below 2010 and cuttings or sidewall cores\r\nbelow this depth showed no direct fluorescence or cut. Paleocene was penetrated\r\nat 2058 m with well-developed sand bodies as is usual in the area. Hence, the\r\nPaleocene contained 190 m net sands of which 25 m consisted of calcareous\r\nsandstone and 90 m of shaly sands. All Paleocene sands were water wet. In the\r\nMaastrichtian chalk some gas shows were recorded on the section 2757 m to 2763\r\nm. Some hydrocarbon saturation was inferred by logs, but an FIT at 2760 m\r\nrecovered 2.750 l of mud with only oil traces after a 25 minutes flow period.\u003c/p\u003e\r\n\r\n\u003cp\u003eCoring started at 1922 m, 45.8 m above\r\nthe Eocene sands. Eight conventional cores were cut from this point down to\r\n2028 m. Two wire line tests were conducted in the oil-bearing zone at 2006.5 m\r\nand 2007.5 m. The latter recovered 5.15 l of oil and 4.75 l of mud filtrate. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 30\r\nMay 1974 as an oil and gas discover","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"346","properties":{"OBJECTID":346,"wlbNpdidWellbore":351,"wlbName":"25/1-5","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 25/1-5 was drilled southeast flank\r\nof the main Frigg structure in the North Sea, about 2.25 km from the discovery\r\nwell 25/1-1. The objectives were to provide data for development of the Frigg\r\nField and calibrate the seismic model.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 25/1-5 was spudded with\r\nthe semi-submersible installation Deepsea Driller on 24 July 1975 and drilled\r\nto TD at 2259 m in the Paleocene Balder Formation. The well was drilled with spud\r\nmud down to 464 m, with KCl mud from 464 to TD. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe Frigg sands were encountered at 1907\r\nm. It was 275 m thick with 225 m net sandstone. The Frigg Formation was gas\r\nbearing down to the GOC at 1976 m, oil bearing down to an an oil/water\r\ntransition zone down to 1982 m and the oil/water contact at 1987 m. The only\r\nshows described in the well were in the Frigg reservoir: "First\r\nsignificant gas increase in drilling was recorded at 1908 m. Sand on cores\r\nshowed a gas bearing facies, i.e. dry outlook, faint direct yellow fluo but\r\nstrong cut. Gas ground began to decrease below 1970 m, becoming nil after 2010\r\nm. Strong direct fluo on cuttings and side wall cores was observed from 1970 m\r\nto 2010 m."\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eTwo cores were cut in the Frigg\r\nFormation. Core 1 was cut from 1914 to 1923 m and core 2 was cut from 1928 to\r\n1937 m. cores were cut. FIT fluid samples were taken at 1979.6 m (oil and\r\nfiltrate), 1981 m (oil and filtrate), 1937 m (gas and filtrate), and 1945.5 m\r\n(gas and filtrate).\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was permanently abandoned on 12\r\nSeptember 1975 as an oil and gas appraisal well.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eTesting\u003c/span\u003e\u003c/b\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp clas","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"347","properties":{"OBJECTID":347,"wlbNpdidWellbore":352,"wlbName":"25/1-6","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eExploration well 25/1-6 is located 12 km\r\nsouthwards of the 25/1-1 well and 6 km south of the Frigg Field boundary. The\r\nmain objective was a Paleocene seismic structure underlined by a strong\r\ndiscontinuous flat seismic event.\u003c/p\u003e\r\n\r\n\u003cp\u003eGeological correlations and geophysical\r\nstudies indicated a detritic sand body belonging to the Heimdal formation. The\r\nCod or Heimdal clay layer could be the closure of this structure.á The\r\nstructurally closed Frigg, Cod, and Danian Sands, and Late Cretaceous chalk\r\nwere secondary objectives. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 25/6-1 was spudded with the\r\nsemi-submersible installation Pentagone 84 on 26 January 1978 after spending 10\r\ndays on the location waiting on weather. No significant problems were\r\nencountered during the drilling to TD at 2895 m in Late Cretaceous limestone.\r\nThe well was drilled with spud mud to 192 m, with CMC/Bentonite from 192 m to\r\n468 m, and with Lignosulfonate/Dextrid mud from 468 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe first interval of interest was the\r\nEocene Frigg Formation from 2107 m to 2150. This interval turned out to be\r\nshaly with thin sand layers up to 3 meter thick only. Some oil shows were\r\nrecorded in the sands. In the lower part of the Frigg Formation a core was\r\ntaken with four thin interbeds of sandstones medium to fine grained and weakly\r\ncemented. These sandstones were fluorescent (light yellow) and gave a\r\nfluorescent, light yellow extract. Massive Heimdal Formation sand was\r\nencountered from 2249 m to 2563 m. The unit has good reservoir characteristics\r\nwith translucent fine to coarse, subrounded to subangular, mostly well-sorted\r\nsand. The porosity of the sandy levels varies from 20 to 25% and net sand\r\nthickness is about 226 m. The unit was water bearing. No shows were encountered\r\nduring the drilling or on the lab. The lower part (2675 m to 2799 m) of the\r\nDanian sequence (Ty Formation) was composed of many intercalations of sandy\r\nlevels and shaly beds. The sandy intervals had poor porosit","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"348","properties":{"OBJECTID":348,"wlbNpdidWellbore":353,"wlbName":"25/2-1","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThe 25/2-1 well was drilled on the top of\r\nthe eastern structure on the WSW-ENE trend of the Frigg Field. The objective of\r\nthis well was the lower tertiary sands, especially Eocene, which are equivalent\r\nto the gas - bearing sand section in the western Frigg wells. Their thickness\r\nrange around 100 m according to the seismic. Sandy interbeds in the upper part\r\nof the cretaceous chalk were considered secondary objective.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 25/2-1 was spudded with the\r\nsemi-submersible installation Neptune 7 on 4 August 1973 and drilled to TD at\r\n2740 m in the Late Cretaceous Hardråde Formation.\u003c/p\u003e\r\n\r\n\u003cp\u003eTop Frigg sand was found at 1915 m, only\r\n8 meters above the average seismic estimate. As expected, the Frigg sand body\r\nwas found underlying the Eocene green and brown-red shales. The net sands are\r\n88 m thick with excellent reservoir qualities (30 % to 24 % on the cores). The\r\ntop of the reservoir stands 7 m deeper than in well 25/1-1. The net pay zone in\r\nthe Frigg Formation includes 56 m of gas bearing and seven m of oil bearing\r\nsand. The gas/oil interface at 1971 m was found exactly at the same depth as in\r\nthe Frigg Field. Two wire-line tests were performed in the gas-zone at 1973 m\r\nand 1974 m. The second of these was plugged by sand. A Third wire line test in\r\nthe transition zone at 1985 m produced some oil with 70% salt water (35 g/l).\r\nPaleocene reservoirs below Frigg were of very good quality too, but all Sands\r\nbelow the Frigg Formation were found water wet.á Only very weak shows were recorded\r\nin the Paleocene (Hermod Formation), the Danian (Ty Formation) and\r\nMaastrichtian (HardrÕde Formation). Two cores were cut in the Frigg Formation,\r\nthe first in the interval 1950 m to 1968 m, and the second in the interval 1973\r\nm to 1991 m.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eAn open hole test was carried out from\r\n1926 to 1938 m Just after setting the 9" 5/8 casing at 1907 m in order to\r\ncheck a new type of sand screen to be used in furthe","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"349","properties":{"OBJECTID":349,"wlbNpdidWellbore":354,"wlbName":"25/2-2","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 25/2-2 is located east of the Frigg\r\nField and south of the Frigg Øst Field, on the top of an E-W trending\r\nstructure. The well was drilled to appraise the 25/2-1 Øst Frigg Discovery made\r\nin September 1973. The main target was lower Eocene sands where seismic\r\nsections displayed a bright spot in the western part of the closure just below\r\nthe Frigg sand horizon. Secondary targets were Danian and Maastrichtian sands.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eAppraisal well 25/2-2 was spudded with the\r\nsemi-submersible installation Deepsea Driller on 31 May 1974 and drilled to TD\r\nat 2740 m in the Late Cretaceous Shetland Group. \u003c/p\u003e\r\n\r\n\u003cp\u003eTop Early Eocene sands (Frigg Formation)\r\nwere encountered at 1949 m, 23 m lower than prognosed. The Hermod Formation\r\ncame in at 2269 m while Danian sand (Ty Formation) was encountered at 2563 m\r\nand chalky limestone (Shetland Group) at 2703 m. Hermod and Ty were water wet.\r\nAn increase in C1 and C2 at around 1950 m during drilling marked the top of the\r\nFrigg Formation reservoir. From electrical logs, FIT's and the DST Gas/oil and\r\noil/water contacts were set at 1964.2 m and 1974.4 m, respectively. Three cores\r\nwere cut from 1991 to 2012.5 m. The cores consisted almost entirely of sand\r\nwith only some thin interbeds of silt in core number 2. Down to 2011 m the\r\ncored sands were brown coloured from oil stain, and direct fluorescence and\r\ncuts were very strong. No shows were observed from 2011 m to 2015.5 m in the\r\nbase 1.5 m of core number 3. The DST carried out in the cored interval produced\r\nonly water. Weak shows were recorded in the Ty Formation sands. Two FIT's at\r\n1952 and 1968.2 in the Frigg Formation reservoir sampled gas and oil and\r\nrecorded formation temperatures of 57.6 °C and 57.9 °C, respectively.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 11\r\nJuly 1974 as an oil and gas appraisal. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eDST 1 carried out from 1983 to 1996 m\r\nproduced 5.1 m3 of salt water (53 g/1).\u003c/p\u003e\r\n\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"350","properties":{"OBJECTID":350,"wlbNpdidWellbore":355,"wlbName":"25/2-3","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 25/2-3 was drilled southwest of the\r\nEast Frigg Field on a Paleocene structure with the objective to increase Frigg\r\narea gas reserves. The main target was sand channels in the Paleocene Balder\r\nFormation. Early Eocene and Danian sands were considered as secondary targets.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eExploration well 25/2-3 was spudded with\r\nthe semi-submersible installation Deepsea Driller on 1 September 1974 and\r\ndrilled to TD at 2795 m in the Late Cretaceous Shetland Group. \u003c/p\u003e\r\n\r\n\u003cp\u003eEocene sands (Frigg Formation) were\r\nencountered at 2073 m, 27 m deeper than expected. The top of the tuff (Balder\r\nFormation) was encountered at 2211 m, 85 m deeper than expected. Both the\r\nHermod (153 m thick) and the Ty (144 m) Formations were well developed in the\r\nwell. The top of the chalk (Shetland Group) was encountered at 2726 m. All the\r\nsandstone sequences encountered in the well were water bearing. No shows were\r\nreported from the well. No cores were cut and no fluid samples taken. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 9\r\nOctober 1974 as a dry hole. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was performed\u003c/p\u003e\r\n\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"351","properties":{"OBJECTID":351,"wlbNpdidWellbore":356,"wlbName":"25/2-4","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 25/2-4 was drilled in the north west\r\ncorner of block 25/2. It lies on the eastern flank of the Viking basin in the\r\nViking Graben and to the east of the Frigg Field and Frigg Kitchen. The main\r\ntargets was the Jurassic with a mapped seismic structure of 30 ms vertical\r\nclosure and 30 square km acreage spreading on the Shell block 30/11. Well\r\n25/2-4 was located on the west flank near the top of the structure. Agreement\r\nwith Shell management was signed for a bottom hole contribution with obligation\r\nfor the operator to reach the Triassic red shales or to set TD at 3360 m. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe well is Reference Well for the Drake\r\nFormation.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eExploration well 25/2-4 was spudded with\r\nthe semi-submersible installation Neptune 7 on 14 may 1975 and drilled to TD at\r\n4384 m in the Triassic Smith Bank Formation. The well was drilled water based\r\nwith salt/gel/Flosal/seawater down to 733 m and with FCL/LC mud from 733 m to\r\nTD. At 3375 m the well kicked due to an under balanced hydrostatic mud\r\npressure.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well penetrated Danian, Paleocene and\r\nEoceneá sandstone sequences (Frigg Formation, Intra Balder Formation\r\nSandstones, Hermod and Ty formations). All these sands were water wet without\r\nshows. In the Late Cretaceous limestones were found fairly well developed\r\noverlying a thick shaly and marly sequence with some more limestone levels,\r\nparticularly in the Campanian and Turonian. The latter limestones contained\r\nsignificant shows, but a production test proved tight formation. The Kimmerian\r\nunconformity was penetrated at 3632 m with 8 m Draupne shale. In the Jurassic\r\ntwo reservoir sandstone sequences were encountered: the Vestland Group and the\r\nStatfjord Formation. The Vestland sequence was first interpreted as oil and gas\r\nbearing from 3640 m to 3708 m (Hugin Formation) with a probable gas/oil\r\ncontact 3660 m and an oil/water contact between 3704 m to 3708 m. Net pay in\r\nthe 25/2-4 Hugin reservoir was estimated around 40 m w","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"352","properties":{"OBJECTID":352,"wlbNpdidWellbore":357,"wlbName":"25/2-5","wlbHistory":"\r\n\r\n\u003cp\u003eWell 25/2-5 is located on the north-west\r\nrim of the Stord Basin and to the north of the main part of the Utsira High in\r\nthe North Sea. The main target was Jurassic sandstones, which appeared\r\npromising after the discovery made in well 25/2-4 where Mid Jurassic (Dogger)\r\nsandstones were found to be hydrocarbon bearing, and also after the positive\r\nresults of 25/4-1. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 25/2-5 was spudded with the\r\nsemi-submersible installation Polyglomar Driller on 8 March 1976 and drilled to\r\nTD at 4000 m in the Triassic Smith Bank Formation. \u003c/p\u003e\r\n\r\n\u003cp\u003eAs anticipated, good reservoirs were\r\nencountered in the early Tertiary, but without any shows (no structural\r\nclosure) Jurassic sandstones present two main reservoirs: The upper reservoir\r\n"Brent sands" (3336 - 3489 m) was oil bearing in 3 zones (3339 m -\r\n3388.5 m, 3448.5 - 3481 m, and 3487 - 3489 m), with a net oil pay of 40 m. Tests\r\nof the upper Brent showed a good productivity. The lower reservoir\r\n"Statfjord sands" (3652 - 3847 m) was oil bearing in two zones (3652\r\n- 3692 m and 3706 - 3763 m), with a net oil pay of 44.5 m, but with lower\r\nporosities than in the "Brent sands". The pressure of the Jurassic\r\nreservoir was hydrostatic (equivalent density = 1.08).\u003c/p\u003e\r\n\r\n\u003cp\u003eFive cores were cut in the Vestland\r\nGroup. Four were cut from 3339.5 to 3372 m in the Hugin Formation and one was\r\ncut from 3476 to 3485 m in the Sleipner Formation. Ten FIT tests were carried\r\nout in the Vestland Group sands. Five were carried out while drilling from 3354\r\nto 3384 m. Of these, oil was recovered in two FITs at 3357.2 and 3382.5 m (density\r\n= 0.804 g/cm3 = 44 deg API). The others were unsuccessful. Another five FITS were\r\ncarried out during DST3. Of these, oil was recovered in FIT no 15 at 3383.8 m and\r\ngas in the 4 others. Nine FITs were carried out in the Statfjord Formation.\r\nNone of these recovered any oil or gas.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 4\r\nAugust as an oil and gas ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"353","properties":{"OBJECTID":353,"wlbNpdidWellbore":358,"wlbName":"25/2-6","wlbHistory":"\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eExploration well 25/2-6 was located in\r\nthe Viking Graben on the same main structure as well 25/2-5 targeting the\r\nJurassic were oil bearing, while the Statfjord sands gave good oil shows.\r\n25/2-6 was drilled on the northwestern flank of a structure that was about ten\r\nyears later discovered as the Frøy Field. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well is Type Well for the Hermod\r\nFormation.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was spudded with the\r\nsemi-submersible installation Polyglomar Driller on 1 August 1977 and drilled\r\nto TD at 3750 m in the Triassic Smith Bank Formation. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well penetrated two Paleocene sands,\r\nthe Hermod Formation from 2221 m to 2361 m and the Ty Formation from 2563 m to\r\n2631 m. No shows were recorded in these sands. The Jurassic contained two major\r\nsandy but somewhat heterolithic sequences in the Vestland Group and Statfjord\r\nFormation. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eFour conventional cores were cut in the\r\nwell, one from 3159.6 m to 3165 m in the Heather Formation, two from 3253.4 m\r\nto 3271.8 m in the Hugin and Sleipner formations, and one from 3509 .7 m to\r\n3518.9 m in the Statfjord Formation. Good oil shows were recorded on the lower\r\npart of the Statfjord core. An extensive pressure and fluid sampling programme\r\nwas carried out in the Jurassic with 19 RFT samples from the interval 3242.5 m\r\nin the Vestland Group and 24 RFT samples and four FIT samples from the interval\r\n3505.1 m to 3648 m in the Statfjord Formation. Fluid samples were taken from\r\nfour depths in the Sleipner and Hugin formations (3243.3 m, 3257.8 m, 3267.5 m,\r\nand 3286 m). Only one of the samples (3286 m) recovered fluid that was\r\nrepresentative for the formation and this sample contained water with dissolved\r\nga","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"354","properties":{"OBJECTID":354,"wlbNpdidWellbore":359,"wlbName":"25/4-1","wlbHistory":"\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 25/4-1 is the discovery well on the\r\nHeimdal Field. The primary objective was Paleocene sand development (which was\r\nconfirmed by the well), while Jurassic sands were regarded as a secondary\r\nobjective. Planned depth was 3500 m.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well is Type Well for the Heimdal\r\nFormation.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 25/4-1 was spudded with the\r\nsemi-submersible installation Neptune 7 on 1 July 1972 and drilled to TD at\r\n4060 m in the Triassic Smith Bank Formation. From 2600 m to 3580 m the well\r\nbuilt some angle (maximum 5 deg), resulting in a 3 m deviation between measured\r\nand true vertical depth at 3580 m. In addition, logger's depth is 6 m deeper\r\nthan driller's depth from seabed to 3525 m. Below 3525 m driller's depth is\r\nequal to logger's depth. This history quotes logger’s depth if not otherwise\r\nstated. While drilling at 3178 m the well started to flow and a lost\r\ncirculation situation followed. The situation was adequately dealt with. The\r\nwell was drilled water based all through.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well penetrated a 356 m thick Heimdal\r\nFormation from 2067 m to 2423 m. The reservoir was composed of more or less\r\nunconsolidated sands with interbedded shales and carbonates. The formation was\r\ngas filled down to a gas/oil contact at 2173 and contained oil in a thin zone\r\ndown to a shale at 2177 m. The OWC could not be seen in the well. The upper\r\nCenomanian rested unconformably on a 14 m thick Oxfordian/Callovian Draupne\r\nFormation sequence, which in turn rested unconformably on the Middle Jurassic\r\nVestland Group at 3185 m. Several permeable reservoirs were penetrated from\r\n3185 m to 3512.5 m (3179 m to 3506.5 m drillers depth) in the Middle Jurassic\r\nto Late Triassic. Four of these were hydrocarbon bear","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"355","properties":{"OBJECTID":355,"wlbNpdidWellbore":360,"wlbName":"25/4-2","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 25/4-2 was drilled ca 6 km ENE of\r\nthe 25/4-1 Heimdal Discovery well, which encountered 106 m gas-bearing sands\r\ngas in the Paleocene Heimdal Formation and several thin sands with gas and oil\r\nin the Jurassic and late Triassic. The aim of well 25/4-2 was to explore the\r\nHeimdal sand section on a separate closure.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 25/4-2 was spudded with the\r\nsemi-submersible installation Neptune 7 on 18 October 1973 and drilled to TD at\r\n2775 m in the Late Cretaceous Jorsalfare Formation. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe well penetrated a 405 m thick section\r\nwith Heimdal Formation sands from 2156.5 m to 2561 m. The reservoir\r\ncharacteristics were quite the same as in well 25/4-1: clean sands with\r\noccurrence of only small shale-sand laminae and a few carbonaceous stringers. A\r\nnine-meter thick oil column was found from top of the reservoir down to an OWC\r\nat 2165.5 m, which was estimated to be 8.5 m higher than in 25/4-1. Other\r\nreservoirs were water-wet except a very thin bed of calcareous sand between\r\n2591 and 2597 m (Våle Formation) with some residual oil according to the log\r\ninterpretation, and where a small methane kick occurred. \u003c/p\u003e\r\n\r\n\u003cp\u003eOne conventional core was cut in the\r\ninterval 2159 m to 2172 m. Only 2166.6 m to 2167.4 m was recovered. Good shows\r\nwith bleeding oil was observed on the recovered piece of core. Three Formation\r\nInterval Tester samples were taken. FIT 1 and 3 were taken at 2162.5 m. The FIT\r\n1 fluid was transferred under bottom hole pressure for PVT studies. FIT 3\r\nrecovered 4.15 1itre of oil, 5.75 litre of filtrate + mud and 136 litre of gas.\r\nFIT 2 at 2165.8 m produced 9.9 1itre of water, filtrate, and mud with some\r\ntraces of oil. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 6\r\nDecember 1973 and has been classified as a minor oil discovery.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was performed in the\r\nwell.\u003c/p\u003e\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"356","properties":{"OBJECTID":356,"wlbNpdidWellbore":361,"wlbName":"25/4-3","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well 25/4-3 is located SW of the\r\nHeimdal field on a Paleocene structure which trends NE-SW and stretches\r\nsouthwards over the block 25/7. The Heimdal sand formation was the main\r\nobjective with a bright spot phenomenon clearly visible on all the seismic\r\nsections through the structure. Seismic mapped vertical closure was assumed to\r\nbe less than 50 m. Danian sands was the secondary target.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 25/4-3 was spudded with the\r\nsemi-submersible installation Deepsea Driller on 13 October 1974 and drilled to\r\nTD at 2714 m in the Late Cretaceous Jorsalfare Formation.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe tuff marker was encountered at 1974\r\nm, 20 m lower than prognosed. Heimdal sands expected around 2075 m were found\r\nat 2125 m. The Heimdal sand contained 3 m gas down to a gas/oil contact at 2128\r\nm and 5 m oil down to a oil/water contact at 2133 m. A 94 m thick sequence of\r\nDanian sands (Ty Formation) was encountered at 2550 m overlying Late Cretaceous\r\nchalky limestones.\u003c/p\u003e\r\n\r\n\u003cp\u003eThree cores were cut in the Heimdal sands\r\nfrom 2128 m to 2144 m. Three Formation Interval Tests were conducted on the\r\ninterval 2125 - 2133 m. FIT 1 and 3 at 2126.2 and 2126.4 m were unsuccessful\r\ndue to mechanical failures. FIT 2 at 2129.7 recovered oil and mud filtrate.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 22\r\nNovember 1974 as an oil and gas discovery.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was performed in the\r\nwell.\u003c/p\u003e\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"357","properties":{"OBJECTID":357,"wlbNpdidWellbore":362,"wlbName":"25/4-4","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell\r\n25/4-4 was drilled on the NW flank of the structure of the Heimdal structure,\r\nnorth of well 2 5/4-1. The objective was to appraise the Heimdal reservoir\r\nextension, to assess its characteristics, and to sample it.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations\r\nand results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eAppraisal\r\nwell 25/4-4 was spudded with the semi-submersible installation Odin Drill on 16\r\nMay 1975 and drilled to TD at 2681 m in the Early Paleocene Våle Formation.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well\r\nencountered 323 m of Heimdal sands with top at 2133 m, and 157 m of Ty sands at\r\n2517 m. The Heimdal Formation consisted of sand with shale interbeds. The sand\r\nwas generally clean, with a few sand-shale laminae. It was hydrocarbon bearing\r\nwith a gas/oil contact at 2172 m, and the oil/water contact at 2175 m in\r\naccordance with what was expected. The Ty sand was water bearing.\u003c/p\u003e\r\n\r\n\u003cp\u003eFour\r\ncores were cut from 2142 m to 2170 m in the Heimdal Formation. The recovery\r\nvaried from 0.5 m to a full 9 m barrel. Poor recovery was mainly due to very\r\nunconsolidated sand. Three Formation Interval Tests were conducted. FIT1\r\nsampled oil from 2173.5 m, FIT2 sampled gas from 2171.4 m, and FIT3 sampled\r\nsalt water from 2190 m.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well\r\nwas permanently abandoned on 7 July as a gas and oil appraisal.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eA drill\r\nstem test was conducted from the interval 2134 m to 2143 m in gas zone of the\r\nHeimdal Formation. It produced 676300 Sm3 gas and 95.8 Sm3 condensate/day. \u003c/p\u003e\r\n\r\n\u003c/html\u003e\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"358","properties":{"OBJECTID":358,"wlbNpdidWellbore":363,"wlbName":"25/8-2","wlbHistory":"\r\n\r\n\r\n\r\n\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 25/8-2 was drilled on the Heimdal\r\nTerrace in the North Sea.\u003c/span\u003e\u003cspan lang=EN-GB\u003eThe objective\r\nwas to test Jurassic and Paleocene age sands located within a structural\r\nclosure.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 25/8-2 was spudded with the\r\nsemi-submersible installation Ross Rig on 9 September 1975 and drilled to TD at\r\n2578 m in Late Triassic sediments of the Statfjord Formation. No significant\r\ndrilling problems were encountered. Initial drilling from the sea floor to 1268\r\nm was with sea water and gel. Below 1268 m sea water and lignosulphonate mud\r\nsystem was used.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well penetrated good reservoir sands\r\nas predicted, but they were water bearing. No Danian or Cretaceous sediments\r\nwere present. Paleocene sediments (Ty Formation) lie unconformable on the Middle\r\nJurassic Sleipner Formation in the well. A small gas show (methane) was found\r\nin the top of the Miocene (Utsira Formation) and scattered oil stained sand\r\ngrains were found in the upper part of Paleocene. No other shows were encountered\r\nin the well.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo cores were cut and no wire line fluid\r\nsamples were taken.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was permanently abandoned on 1\r\nOctober 1975 as a dry well.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eTesting\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo drill stem test was performed.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"359","properties":{"OBJECTID":359,"wlbNpdidWellbore":364,"wlbName":"25/8-3","wlbHistory":"\r\n\r\n\r\n\r\n\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 25/8-3 was drilled in the northern\r\npart of the Utsira High in the North Sea. The main purpose was to establish the\r\npresence of a thick accumulation of Paleocene oil sand, and evaluate the Paleocene\r\nsand-shale distribution and reservoir quality in the area. The top of the\r\nreservoir was anticipated to be at 1668 m subsea.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 25/8-3 was spudded with the\r\nsemi-submersible installation Glomar Biscay II on 20 March 1981 and drilled to\r\nTD at 1868 m in the Danian Ekofisk Formation. A total of 159.25 hours, or more\r\nthan 23% of the total time spent on this well, were lost due to downtime in the\r\ncategories of: Subsea and Surface BOP Equipment Repairs and Casing and\r\nWellhead. The well was drilled seawater and hi-vis pills down to 219 m and with\r\nseawater/gel/Lignosulphonate from 219 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe top of the Paleocene reservoir (Hermod\r\nFormation) was encountered 64.5 m lower than predicted at 1757.5 m and the net\r\noil sand was 9.5 m thick, which is close to what was found in the 25/8-1 well\r\nto the southwest. The results were disappointing as there was much less sand\r\nthan had been anticipated. However, shows of hydrocarbons were found in thin\r\nsand stringers throughout the interval 1667-1784 m, suggesting that the OWC\r\nmight be at 1784 m (1759 m TVD SS), about the same as in the Balder field.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eOne core was cut from 1859 m to 1868 m in\r\nthe Ekofisk Formation Chalk/Limestone and recovered 90%. Reservoir data was\r\nlimited to mud logs and electric logs. No wire line fluid samples were taken.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was permanently abandoned on 17\r\nApril 1981. It is classified as an oil appraisal of the 25/8-10 S Ringhorne\r","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"360","properties":{"OBJECTID":360,"wlbNpdidWellbore":365,"wlbName":"25/10-5","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThe 25/10-5 well was drilled to establish\r\nthe presence of an accumulation of Eocene oil sand in the western part of the\r\nBalder Field, and evaluate the geologic concept of sand-shale distribution and\r\nreservoir quality.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 25/10-5 was spudded with the\r\nsemi-submersible installation Glomar Biscay II on 15 June 1981 and drilled to\r\nTD at 2011 m in the Late Jurassic Viking Group. The well was drilled with sea\r\nwater/gel/lignosulphonate.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe top of the Early Eocene reservoir\r\nwas encountered at 1733 m (1708 m sub sea), as prognosed.\r\nThe reservoir consisted of thin sandstone beds interbedded with shale and was\r\noil bearing. A 49.5 m gross oil column was found down to an OWC at 1782.5 m.\r\nThe net oil sandstone thickness was 18.2 m. Late Eocene Grid Formation\r\nsandstone was penetrated at 1398 m to 1443 m and Paleocene Heimdal Formation\r\nsandstone from 1905 m to 1929 m. These were both water wet without shows.\u003c/p\u003e\r\n\r\n\u003cp\u003eFour cores were cut in the Lower Eocene\r\nreservoir sequence. No wire line test or fluid sampling was carried out.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 17\r\nJuly 1981 as an oil appraisal well.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eTwo drill stem tests were performed in\r\nthe Early Eocene reservoir. DST 1 perforated the interval 1756 m to 1753 m and\r\nproduced 171 Sm3 oil/day. The oil gravity was 25.3 deg API and the gas/oil ratio\r\nwas 59 m3/m3. DST2 perforated the intervals 1732 - 1740 m and 1756 - 1763 m. It\r\nproduced 515 Sm3 oil/day. The oil gravity in DST2 was 25.5 deg API and the gas/oil\r\nratio was 59 m3/m3. \u003c/p\u003e\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"361","properties":{"OBJECTID":361,"wlbNpdidWellbore":366,"wlbName":"25/11-5","wlbHistory":"\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 25/11-5 was drilled ca 4 km north\r\nwest of the 25/11-1 Balder discovery well on the Utsira High in the North Sea. The\r\nwell was designed to evaluate a sand build up and/or structural closure at the\r\nMiddle Paleocene horizon top. The location was mapped structurally high to the\r\nadjacent wells 25/11-1, 25/11-2, 25/10-1, and 25/10-3.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 25/11-5 was spudded with the\r\ndrillship Drillmaster on 3 April 1974 and drilled to TD at 2164 m in Triassic red-grey\r\nclays, and grey-green shale. Sloughing shale was the only drilling problem and\r\nthis was overcome by converting the Drispac mud system to a ligno-gel seawater\r\nmud system. The well was drilled with Drispac from approximately 1000 to 1400\r\nm, and with lignosulphonate/gel/seawater from ca 1400 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well penetrated the Utsira Formation\r\nand a Skade Formation sand and then entered a ca 700 m thick section of shales\r\nbelonging to the lower Hordaland Group before top Balder formation was\r\nencountered at 1661 m. Significant oil bearing sands in the interval from 1714 to\r\n1771 m were confirmed by sidewall cores and Schlumberger electric logs. The\r\nlower part of this interval tested oil at good rates. Additional shows in traces\r\nof sand in cuttings at 1838 - 1847 m were believed to be sloughings from the\r\noil sand above. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eOne conventional core was cut from 1723.3\r\nto 1725.5 m. Six attempts at FIT's were attempted with one successful at 1744.1\r\nm. This test recovered 0.33 Sm3 gas, 4.5 l oil, 2.3 l filtrate and 0.8 l mud.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was permanently abandoned on 8\r\nMay1974 as an oil appraisal.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eTesting\u003c/span\u003e\u003c/b\u003e\u003c","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"362","properties":{"OBJECTID":362,"wlbNpdidWellbore":367,"wlbName":"25/11-6","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-US\u003eWell 25/11-6 was drilled ca 1 km west of\r\nthe 25/11-1 Balder discovery well on the Utsira High in the North Sea. The\r\nprimary objective was to delineate the Paleocene E-70 oil sand and older sands\r\nwhich are developed as topographic mounds (stratigraphic traps) in the Balder\r\nField area. A secondary objective was Danian sand which had oil shows in an\r\noffset well.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well \u003c/span\u003e\u003cspan lang=EN-US\u003e25/11-6\r\n\u003c/span\u003e\u003cspan lang=EN-GB\u003ewas spudded with the semi-submersible installation Norskald\r\non 20 August 1978 and drilled to TD at 1948 m in the Early Cretaceous Cromer\r\nKnoll Group. The well was drilled with seawater/gel/lignosulphonate.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well penetrated the Utsira Formation,\r\na Skade Formation sand and a Grid Formation sand and then penetrated a ca 175 m\r\nthick section of shales belonging to the lower Hordaland Group before top\r\nBalder formation was encountered at 1646 m. An 8 m thick shaly Intra Balder\r\nFormation sand at 1664 m had some shows and appeared to be oil bearing on the\r\nlogs. Two Paleocene Heimdal Formation sand units with tops at 1717.5 m and\r\n1763.0 m were found oil bearing down to a clear oil-water contact at 1785.3 m\r\nin the lower sand unit. This defines the OWC of the Balder field at 1760 m MSL.\r\nThe Danian sand (Ty Formation) was encountered at 1877 m, but was water wet.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eFive cores were cut in the Lista and\r\nHeimdal Formation, recovering a total of 25.5 m core from the interval 1713 to\r\n1797 m. Wire line fluid samples were attempted, but with no success.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was permanently abandoned on 1\r\nOctober 1978 as an oil appraisal.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eTesting\u003c/span\u003e\u003c/b","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"363","properties":{"OBJECTID":363,"wlbNpdidWellbore":368,"wlbName":"25/11-7","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-US\u003eWell 25/11-7 was drilled ca 3 km\r\nwest-south west of the 25/11-1 Balder discovery well on the Utsira High in the\r\nNorth Sea. The primary objective was to delineate topographic mounds developed\r\nin the Paleocene sands of the Balder Field. The primary targets were the Zone\r\nII sand (E-70 sand) which was found oil-bearing in the 25/11-5 and the Zone I-B\r\nsands which were found oil-bearing in the 25/11-6.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 25/11-7 was spudded with\r\nthe semi-submersible installation Norskald on 3 October 1978 and drilled to TD\r\nat 1944 m in the Late Cretaceous Tor Formation. The well was drilled with Seawater/Gel/Lignosulphonate.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well penetrated the Utsira Formation\r\nand several Skade Formation sands and then penetrated a ca 600 m thick section\r\nof shales belonging to the lower Hordaland Group before top Balder Formation\r\nwas encountered at 1697 m. The Balder Formation contained some shaley sands\r\nwith poor to no oil shows. The massive I-B sand at 1750.3 m (Heimdal Formation)\r\nwas the only significant oil sand in the well. The well proved 36 m of net oil\r\nsand with a clear oil-water contact at 1786.5 m (1761.5 m MSL), in reasonable\r\nagreement with the Balder Field contact at 1760 m MSL established in 25/11-6. The\r\nZone II (E-70) sand was absent, or possibly an unrecognizable part of the I-B\r\nSand.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eA total of 20.35 m core was recovered in\r\nfour cores from the interval 1748.6 to 1772.3 m in the Lista and Heimdal\r\nFormations. No wire line fluid samples were taken.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was permanently abandoned on 27\r\nOctober 1978 as an oil appraisal well.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eTesting\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp cl","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"364","properties":{"OBJECTID":364,"wlbNpdidWellbore":369,"wlbName":"25/11-8","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-US\u003eWell 25/11-8 was drilled ca 3 km\r\nwest-north west of the 25/11-1 Balder discovery well on the Utsira High in the\r\nNorth Sea. The primary objective was to establish the presence of, and closure\r\non, the thick accumulation of Paleocene zone IB sand in the central part of the\r\nBalder Field, evaluate the geologic interpretation of sand distribution and\r\nreservoir quality in this field and test the flow potential and nature of the\r\nhydrocarbons present.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 25/11-8 was spudded with\r\nthe semi-submersible installation Dyvi Alpha on 8 September 1979 and drilled to\r\nTD at 1950 m in the Early Paleocene Ekofisk Formation. The well was drilled\r\nwith Seawater/Gel/Lignosulphonate.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well penetrated the Utsira Formation\r\nand several Skade Formation sands and then penetrated a ca 600 m thick section\r\nof shales belonging to the lower Hordaland Group before top Balder Formation\r\nwas encountered at 1655 m. The well encountered two massive sand units in the Paleocene\r\nHeimdal Formation at 1721.5 m and 1743.8 m (dinoflagellate zones IB and II,\r\nrespectively), interpreted as sand lobes deposited from sand-rich turbidity\r\ncurrents in the Balder Deep Sea Fan Complex. Both sands were oil bearing down\r\nto an OWC at 1785 m (1760 m MSL). Some thin sands from about 1705 m to 1720 m,\r\noverlying the massive sands, also appeared to be oil-bearing, and there were\r\ngood shows on a core three meter below the OWC. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNine cores were taken in the interval\r\n1722.5 m to 1800.4 m in the Heimdal Formation. Cores 1 and 4 had no recovery;\r\nthe remaining cores retrieved a total of 41.7 m. No wire line fluid samples\r\nwere taken.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was permanently a","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"365","properties":{"OBJECTID":365,"wlbNpdidWellbore":370,"wlbName":"25/11-10","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 25/11-10 was drilled to appraise the\r\nBalder Field on the Utsira High in the North Sea. The objective was to\r\nestablish the presence of a thick accumulation of oil sand in the southern part\r\nof the Balder Field, and evaluate the geologic concept of sand-shale\r\ndistribution and the reservoir quality of the Paleocene sands.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 25/11-10 was spudded with\r\nthe semi-submersible installation Glomar Biscay II on 20 January 1981 on and\r\ndrilled to TD at 1988 m (1985 m logger's depth) in the Danian age chalk of the Ekofisk\r\nFormation. The well was drilled with seawater/gel/Lignosulphonate mud.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe Paleocene Heimdal Formation reservoir\r\nsands anticipated to be present in this well were found at 1786 m, significantly\r\ndeeper than prognosed and below the field oil-water contact. Gross thickness of\r\nthe sands was 128.2 m with an average porosity of 31.4%. They were water wet. The\r\nsands were found similar to those found in 25/11-7 to the north. Only thin\r\nstringers (2.5 m totally) with shows between 1757 m and 1785 m were found in\r\nthe Sele and Lista formations. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo cores were cut and no wire line fluid\r\nsamples were taken.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was permanently abandoned on 17\r\nFebruary 1981 as a dry well with shows.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eTesting\u003c/span\u003e\u003c/b\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo drill stem test was performed.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"366","properties":{"OBJECTID":366,"wlbNpdidWellbore":371,"wlbName":"25/11-11","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 25/11-11 was drilled to appraise the\r\nBalder Field on the Utsira High in the North Sea. The objective was to\r\nestablish the presence of an accumulation of oil sand in the western part of\r\nthe Balder Field,\u003c/span\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003cspan lang=EN-GB\u003eand evaluate\r\nthe geologic concept of sand-shale distribution and reservoir quality. The top\r\nof the reservoir was anticipated to be at 1708 m MSL.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 25/11-11 was spudded with the\r\nsemi-submersible installation Glomar Biscay II on 18 February 1981 and drilled\r\nto TD at 1960 m in the Danian age chalk of the Ekofisk Formation. The well was\r\ndrilled with seawater and gel/lignosulphonate.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eOne main oil sand of Paleocene age (Heimdal\r\nFormation) was encountered at 1754 m (1729 m TVD MSL). It was 141.5 m thick and\r\nwas oil-bearing in the upper 29 m down to an OWC at 1783 m (1758 m TVD MSL).\r\nThis OWC was in agreement with the general field OWC in the area. Average\r\nporosity in the oil sand was 32.6%. Shows of hydrocarbons were also present in a\r\n16 m thick Intra Balder Formation Sandstone with top at 1698 m, and in thin\r\nsand stringers within the Sele Formation.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo cores were cut and no wire line fluid\r\nsamples were taken.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was permanently abandoned on 18\r\nMarch as an oil appraisal.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eTesting\u003c/span\u003e\u003c/b\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo drill stem test was performed.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"367","properties":{"OBJECTID":367,"wlbNpdidWellbore":372,"wlbName":"25/11-12","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 25/11-12 was drilled to appraise the\r\nBalder Field on the Utsira High in the North Sea. The objective was to\r\nestablish the presence of a thick accumulation of oil sand in the north-eastern\r\npart of the Balder Field, and evaluate the geologic concept of sand-shale\r\ndistribution and the reservoir quality of the Paleocene sands.\u003c/span\u003e\u003cspan\r\nlang=EN-GB\u003e \u003c/span\u003e\u003cspan lang=EN-GB\u003eThe top of the reservoir was anticipated to\r\nbe at 1717 m TVD MSL.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 25/11-12 was spudded with\r\nthe semi-submersible installation Glomar Biscay II on 18 April 1981 on and\r\ndrilled to TD at 1918 m in the Danian age chalk of the Ekofisk Formation. The\r\nwell was drilled with seawater/gel/Lignosulphonate mud.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe Sele Formation had thin stringers of\r\nsand with oil shows, but no significant Paleocene sands were developed above\r\nthe Heimdal Formation in this well. Massive Paleocene Heimdal Formation sands\r\nwere encountered at 1784.5 m (1759.5 m TVD MSL) and 1860 m (1835 m TVD MSL).\r\nThe upper sand is 65 m thick and had oil shows evident by sidewall cores at\r\n1785 m and 1786 m. The lower sand is 20 m thick and was entirely water-bearing\r\nwith no shows. The Balder Field oil/water contact is generally thought to be at\r\n1785 m (1760 m). \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo cores were cut and no wire line fluid\r\nsamples were taken.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was permanently abandoned on 7\r\nMay 1981as a dry well with shows.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eTesting\u003c/span\u003e\u003c/b\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo drill stem test was performed.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"368","properties":{"OBJECTID":368,"wlbNpdidWellbore":373,"wlbName":"25/11-13","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 25/11-13 was drilled to appraise the\r\nBalder Field on the Utsira High in the North Sea. The objective was to\r\nestablish the presence of a thick accumulation of oil sand in the southern part\r\nof the Balder Field, and evaluate the sand-shale distribution and the reservoir\r\nquality of the Paleocene sands. Top of the Paleocene reservoir sands was\r\nanticipated at 1702 m MSL.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 25/11-13 was spudded with\r\nthe semi-submersible installation Glomar Biscay II on 10 May 1981 and drilled\r\nto TD at 1932 m in the Late Cretaceous Tor Formation. The well was drilled with\r\nseawater and bentonite down to 500 m and with\r\nseawater/bentonite/lignosulphonate mud from 500 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eShows of hydrocarbons were present in\r\nthree 1-2 m thick Intra-Balder Formation sand beds between 1723 and 1743 m. The\r\nmain oil-bearing Paleocene reservoir sand (Hermod Formation) was encountered between\r\n1768.8 m to 1816.8 m. It contained oil down to the OWC at 1783 m (1758 m MSL),\r\nwhich is close to the regional Balder Field OWC. The average porosity in the\r\noil zone was 33.5 %. Poorly developed 4 m thick Heimdal Formation sand was\r\npenetrated at 1858 m, and then a massive Ty Formation sandstone was penetrated\r\nfrom 1875 m down to the Shetland Group at 1908 m.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo cores were cut and no wire line fluid\r\nsamples were taken.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was permanently abandoned on 29\r\nMay 1981 as an oil appraisal.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eTesting\u003c/span\u003e\u003c/b\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo drill stem test was performed.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"369","properties":{"OBJECTID":369,"wlbNpdidWellbore":374,"wlbName":"25/12-1","wlbHistory":"\u003cp\u003eWell 25/12-1 is located on the Patch Bank\r\nRidge between the Utsira High and the Stord Basin in the North Sea. The well\r\nwas designed to test Paleocene sand and late Cretaceous chalk prospects (found\r\noil bearing in the adjacent Esso blocks). Additional objectives were the\r\nMesozoic and possibly older sands, which formed part of a monocline, east\r\ndipping subcrop below this structure. The well was programmed to investigate\r\nthe entire sedimentary sequence down to igneous/metamorphic basement,\r\ninterpreted to occur at approximately 2743 m.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 25/12-1 was spudded with the\r\nsemi-submersible installation SEDCO 135 G on 3 October 1973 and drilled to TD\r\nat 2865 m in rocks of possible Devonian age. The spud was delayed due to rig\r\nrepairs in Hamburg. This resulted in the well being drilled during the worst of\r\nthe winter weather. Due to adverse weather and bad anchoring conditions, 14.5\r\ndays were spent anchoring the rig. A total of 19.7 days was lost directly due\r\nto weather during drilling and abandoning. A further 8.7 days were lost\r\nrepairing underwater equipment, much of which was also due to weather damage.\r\nThe well was drilled with seawater and bentonite down to 463 m and with a\r\nseawater / lignosulphonate mud from 463 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe Oligocene-Eocene sands of the\r\nHordaland Group were water bearing and the Paleocene sands absent. The Chalk\r\nsection (Tor and Hod formations) showed poor reservoir characteristics and was\r\nalso water bearing. Below the Late Jurassic shale sequence sands and\r\nconglomerates of Middle Jurassic age and older were penetrated. The sands were\r\npenetrated in a down dip position on a monoclinal structure rising towards\r\nblock 25/11. Middle Jurassic (Vestland Group) sands were encountered at 2244 m\r\nwith porosity up to 30 %, averaging 18 %. Conglomerates were encountered at\r\n2425 m and extended down to 2671 m. From this point down to TD at 2865 m the\r\nwell drilled a thick water bearing sand sequence. This possible Devonia","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"370","properties":{"OBJECTID":370,"wlbNpdidWellbore":375,"wlbName":"29/6-1","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 29/6-1 was drilled ca 2 km west of\r\nthe UK border on the eastern margin of the East Shetland Basin. The primary\r\nobjective was the Brent Group in a fault block separate from the Hild structure\r\nsome few km to the southwest. The secondary objective was the Statfjord\r\nformation. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 29/6-1 was spudded with the\r\nsemi-submersible installation SEDCO 707 on and drilled to TD at 4832 m. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was spudded by "Sedco\r\n707" on 12.10.81. When drilling the 17 1/2" pilot hole (with 1.1 sg mud)\r\nin the 24" section, mud losses occurred at 870 m. The hole was displaced\r\nto seawater and operations continued down to 1205 m where the 24" casing\r\nwas set. Further drilling went with increasing mud weights due to tight hole\r\nproblems, to a point where the overbalance considerably reduced penetration\r\nrate. Due to high deviation the pipe became differentially stuck at 4664 m. The\r\nwell was planned to be vertical, but ended up severely deviated. From 3973 m to\r\n4097 m hole inclination increased from 5 degrees to 10.5 degrees, increasing to\r\n15.5 degrees by 4155 m, as a result of the increased dip of the bedding planes.\r\nAt 4155 m a pendulum drill assembly was used but the hole inclination continued\r\nto increase to 19.5 degrees. By 4211 m the angle had reduced to 17 degrees but\r\nagain increased to a maximum of 21 degrees by 4457 m, and then decreased to\r\n20.25 degrees by 4570 m. Below this depth, surveys were not possible due to the\r\nhole conditions with overpull and stuck pipe on the connections and tight hole\r\non trips. Keyseating, washout in the sandstones and the swelling nature of the\r\nclays in the Dunlin formation added to the problem caused by hole angle. At TD Schlumberger\r\nHDT log was run and the ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"371","properties":{"OBJECTID":371,"wlbNpdidWellbore":376,"wlbName":"30/3-1","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 30/3-1 is located just north of the\r\nHuldra Discovery. It was planned to be drilled in two phases and the primary\r\nobjective was to test sandstones of the Brent Group. Secondary objectives were\r\nsandstones in the Paleocene and in the Lower Jurassic, Cook and Statfjord\r\nformations.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 30/3-1, Phase I was spudded with the\r\nsemi-submersible installation Nordskald and drilled to 3718 m in claystone and\r\nmarls of the Early Cretaceous Cromer Knoll Group. Phase I was drilled without\r\nserious problems but the 12 1/4" hole section had to be cut shorter than\r\noriginally planned due to lost circulation and possibly higher pore pressures\r\nthan prognosed. The mud gas readings were relatively high through the 17 1/2"\r\nsection causing long periods of circulation. The well was drilled with seawater\r\nand hi-vis pills down to 212 m, with a gel mud from 212 m to 985 m, and with a\r\nSpersene XP 20/Magcogel/nut plug mud from 985 m to TD. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe Paleocene did not contain good\r\nreservoirs. Shows and live oil in the mud were however recorded in predominant\r\nclaystone lithology from 1910 m to 2470 m. No conventional cores were cut and\r\nno fluid samples taken. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was suspended on 7 September as\r\na dry hole after the 9 5/8" casing was run. The plan was to re-enter the\r\nwell later, using a rig equipped with a 15000 psi BOP stack and drill through\r\nthe Jurassic sandstones.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was performed\u003c/p\u003e\r\n\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"372","properties":{"OBJECTID":372,"wlbNpdidWellbore":377,"wlbName":"30/4-1","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 30/4-1 is located north of the Hild\r\nDiscovery and west of the Oseberg Field. The main target was Middle Jurassic\r\nsandstones in a complex fault and dip-controlled closure. Secondary targets\r\nwere Palaeogene sands (Balder and Sele Formations) and possible Late Jurassic\r\nsands, both in simple dip closures. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 30/4-1 was spudded with the\r\nsemi-submersible installation SEDCO 707 on 1 November 1978 and drilled to TD at\r\n5454 m in the Early Jurassic Dunlin Group. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe well penetrated a mainly argillaceous\r\nPalaeogene section. However, a distinct interval of interbedded thin\r\nargillaceous water-bearing sandstones (beds 1 - 3 m thick) with thicker\r\nmudstone intervals was drilled between 2116.5 and 2162.5. The net/gross ratio\r\nof this interval was about 0.2 (20%) and the sandstone porosities average\r\naround 30% (from Schlumberger logs). The well then penetrated a thick\r\nargillaceous Cretaceous and Late Jurassic interval. No Late Jurassic sandstones\r\nwere developed. Water bearing, Middle Jurassic sandstones of the Brent\r\nGroup were encountered at 5181.5 m. This target group was 218.2 m\r\nthick, had a net/gross ratio of about 0.66 (66%) and had sandstone porosities\r\nranging from around 4-16% (from Schlumberger logs). Shows were recorded in\r\nlimestones in the interval 2545 m to 2570 m, with weaker shows extending down\r\nto 2630 m. Weak shows were also noted in the interval 2900 m to 3000 m.\r\nGeochemical analyses of cuttings confirmed migrant "medium gravity oil"\r\nin the interval 2570 m to 2630 m. No conventional cores were cut. Wire line RFT\r\nsamples were attempted but all failed.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned as dry\r\non 14 May 1979.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was performed\u003c/p\u003e\r\n\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"373","properties":{"OBJECTID":373,"wlbNpdidWellbore":378,"wlbName":"30/4-2","wlbHistory":"\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 30/4-2 was drilled test an easterly\r\ndipping fault block on the western margin of the Viking Graben. The primary\r\ntarget was the Brent Group, which had already been proven to contain gas\r\ncondensate by well 30/7-6 located 3 km to the South on the same structure.\r\nSecondary objectives were to test Palaeocene and Lower Eocene sandstones, and\r\nthe Statfjord Formation. Well 30/7-2 had earlier encountered a hydrocarbon\r\ncolumn with dry gas overlying heavy oil in the uppermost part of the Eocene\r\nFrigg Formation.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 30/4-2 was spudded with the\r\nsemi-submersible installation SEDCO 707 on 16 November 1979 and drilled to TD\r\nat 4775 m in the Triassic Hegre Group. Bad weather caused some delay, and on 12\r\nMarch, the drill string was hung-off due to adverse weather conditions. Whilst\r\nretrieving the running assembly an influx from the well was observed. The\r\ninflux was bull-headed and it took five days before the well was in stable\r\nconditions again. Otherwise, no significant incident happened in the\r\noperations. The well was drilled with seawater and gel down to 1096 m, with\r\nlignosulphonate/Drispac/Gypsum mud from 1096 m to 2530 m, and with\r\nlignosulphonate/Poly-rx from 2530 to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe Frigg Formation was encountered\r\nwater-wet without shows at 1820 m, 36.5 m below the OWC defined in the 30/7-2\r\nFrigg discovery. The Brent Group was encountered at 3779 m. Brent contained\r\ngas/condensate and had excellent poroperm characteristics. The gas-water\r\ncontact established between 3876.5 m and 3893.5 m in the Ness Formation. The\r\nStatfjord Formation was encountered water-wet at 4337 m with only some poor\r\nshows in the top. Pressure analysis showed that it was not communicating with\r\nthe Brent Group.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"374","properties":{"OBJECTID":374,"wlbNpdidWellbore":379,"wlbName":"30/5-1","wlbHistory":"\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell is located centrally in the northern\r\nViking Graben of the North Sea. It was the most northerly well drilled in\r\nNorwegian waters of the North Sea when it was drilled. Primary objectives of\r\n30/5-1 were Paleocene sands, thought to\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003ebe productive in the Frigg Field and the\r\nrecently discovered Heimdal Field, and potential sand or carbonate reservoirs\r\nin\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003ethe Early Cretaceous. The Late Cretaceous\r\nChalk found so prospective in the south was considered to be a secondary\r\nobjective in view of the possible northward shaling out of that formation.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 30/5-1 was spudded with the\r\nsemi-submersible installation Transworld 61on 17 May 1972 and drilled to TD at 4124\r\nm in the Early Cretaceous Åsgard Formation. The well was drilled with seawater\r\nand Lignosulphonate with additions of a total of 329 bbls of diesel oil.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eIn the main Paleocene objective a few\r\nthin water-bearing sand-streaks were present, and in the secondary Upper\r\nCretaceous objective, the Chalk Formation, as expected, had virtually shaled\r\nout. Between a depth of 3475 and 3604 m four streaks of limestone occur,\r\nranging in thickness from 1 - 3 m. The mud became gas cut while drilling the\r\ninterval. From petrophysical logs the limestone streaks appeared to be gas bearing\r\nwith porosities from 9 to 20% and water saturations in the range 20 - 60%. They\r\nwere the only intervals recognisable from logs containing hydrocarbons. The\r\ntotal thickness of these limestone stringers was insufficient to justify a\r\ntest. No \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eOne core was taken at TD from 4114.8 to 4123.9\r\nm with a recovery of 5.6 m (62. 5%). No wire lin","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"375","properties":{"OBJECTID":375,"wlbNpdidWellbore":380,"wlbName":"30/6-1","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 30/6-1 was drilled on the Oseberg\r\nFault block in the North Sea. The primary objective was to penetrate sandstones\r\nof Middle Jurassic age and to evaluate their possible content of hydrocarbons.\r\nSecondary objectives were sandstones of Lower Jurassic and Paleocene age. The\r\nwell is Reference well for the Statfjord Group.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 30/6-1 was spudded with the semi-submersible\r\ninstallation Deepsea Saga on 18 June 1979 and drilled to TD at 3175 m in the\r\nTriassic Lunde Formation. Problems with setting the 9 5/8” casing at 2443 m\r\ncaused an 8 days delay in the drilling phase. Also gumbo problems were\r\nencountered in the interval 1000 – 1600 m and 4 days rig time as lost due to\r\nthis. Otherwise operation proceeded without significant problems. The well was\r\ndrilled with spud mud down to 895 m and with a lignosulphonate/bentonite mud\r\nfrom 895 m to 2456 m and with chromium-lignosulphonate/bentonite mud from 2456\r\nm to TD. Diesel was added at 1720 m to reduce problems with sloughing shales. A\r\n6% to trace levels of oil was recorded in the mud from this depth to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe Cretaceous Jorsalfare Formation had\r\n6.75 m of net pay gas in thin sandstones with average porosity of 29% and water\r\nsaturation of 39.3%. The Brent Group was encountered at 2285 m and was\r\ngas/condensate filled in 38.75 m of net pay sandstones with average porosity of\r\n22.5% and water saturation of 29.2%. The hydrocarbon/water contact was not\r\nencountered in the well. The Dunlin Group was water bearing with 45 m of net\r\nsand with an average porosity of 24.6%. The Statfjord Group was water bearing\r\nwith 235 m of net sand with an average porosity of 21.4%. Weak shows were\r\ndescribed on conventional and sidewall cores in sandstones from below the\r\nhydrocarbon","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"376","properties":{"OBJECTID":376,"wlbNpdidWellbore":381,"wlbName":"30/6-2","wlbHistory":"\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 30/6-2 was drilled to appraise the\r\n30/6-1 Oseberg discovery. Well 30/6-1 found gas in the Brent Group and water-filled\r\nreservoirs in the Dunlin and Statfjord groups. The primary objectives were to\r\ntest the Dunlin and Statfjord sandstones in a structurally higher setting on\r\nthe Oseberg Alpha structure. Secondary objective was appraisal of the Brent\r\nGroup hydrocarbons.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 30/6-2 was spudded with\r\nthe semi-submersible installation Deepsea Saga on 24 September 1979 and drilled\r\nto TD at 2890 m in the Triassic Hegre Group. Tight hole became a serious\r\nproblem at 1313 m. This was cured with salt water and diesel addition. Five\r\ndays were counted as non-productive due to bad weather and fishing for lost\r\nobjects in hole. The well was drilled with spud mud down to 736 m, and with Chromium-Lignosulphonate/bentonite\r\nmud from 736 m to TD. After the diesel addition at 1313 m the mud contained 8%\r\ndiesel. The diesel content became slowly diluted to 0.25% at TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe Brent Group was penetrated from 2191\r\nto 2237. It is 46 m thick and gas bearing. The hydrocarbon/water contact was\r\nnot seen in the well. The underlying Dunlin and Statfjord groups were both\r\nwater bearing. Oil shows were described on cuttings and 39% water saturation\r\nwas calculated, from top Brent and all through the Shetland Group up to 2165 m.\r\nFurther oil shows on cuttings and core were described at 1945 to 1955 m in the\r\nBalder Formation, on cores and cuttings in the Dunlin Group, and on the\r\nStatfjord core.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eA total of seven cores were recovered in\r\nthe interval from 2202 to 2238.5 m in the Brent Group, 2435 m to 2437.5 m, and\r\n2444.5 to 2454.5 m in the Dunlin Group, and 2571 to 2577 m in the top of ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"377","properties":{"OBJECTID":377,"wlbNpdidWellbore":382,"wlbName":"30/6-3","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 30/6-3 was drilled on the Alpha\r\nstructure situated in the south-western part of block 30/6. The objective of\r\nthe well was to penetrate sandstones of Middle Jurassic age and to evaluate\r\ntheir possible content of hydrocarbons.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 30/6-3 was spudded with\r\nthe semi-submersible installation Deepsea Saga on 16 December 1979 and drilled\r\nto TD at 2940 m, 56 m into the Statfjord formation. No significant problem was\r\nencountered in the operations, but 13.5 days were lost due to bad weather. The\r\nwell was drilled with spud mud down to 1757 m and with chrome\r\nlignosulphonate/bentonite mud from 1757 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eOil shows were recorded in\r\nclaystone/siltstone cuttings at 1993 to 2023 m, in siltstone cuttings at 2095\r\nm, and in limestone cuttings from 2253 m to 2296 m and 2317 m to 2350 m. Top\r\nBrent Group came in at 2421 m. It consisted of sandstone interbedded with shale\r\nand coals with a main reservoir sand from 2480 to 2513 m. Gas/condensate was\r\nproven all through the reservoir. The hydrocarbon/water contact could not be\r\ndefined, but the presence of hydrocarbons down to the base of the reservoir\r\nindicated the contact to be located down flank on the structure. The sandstones\r\nof Early Jurassic age ("Intra Dunlin Sand" and the Statfjord Group) were\r\nwater bearing. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eFour cores were cut in the interval from\r\n2421 to 2458 m. An RFT fluid sample was taken at 2499 m. FIT fluid samples were\r\ntaken at 2279 m (traces of gas), 2422 m (gas), 2451 m (small amounts of 32.6\r\ndeg API oil), and 2463 m (gas).\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was permanently abandoned on 7\r\nMarch 1980 as a gas/condensate appraisal.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBo","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"378","properties":{"OBJECTID":378,"wlbNpdidWellbore":383,"wlbName":"30/6-4","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 30/6-4 was drilled on the Alpha\r\nstructure on the Gullfaks fault block in the North Sea. The primary objective\r\nwas to test hydrocarbon accumulations in Middle Jurassic sandstones and to\r\ndefine the hydrocarbon contacts. Gas was the expected hydrocarbon phase.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 30/6-4 was spudded with the\r\nsemi-submersible installation Deepsea Saga on 17 February 1981 and drilled to\r\nTD at 2942 m in the Early Jurassic Amundsen Formation. Total depth for the well\r\nwas reached 10 days before prognosed although 5 days were spent on rig repair\r\nwhen the heave compensator fell down. Apart from this accident no major\r\nproblems were encountered in the drilling phase. The well was drilled in\r\nfavourable weather condition. The well was drilled with spud mud down to 962 m,\r\nwith KCl/polymer mud from 962 m to 1862 m, and with gel/lignosulphonate mud\r\nfrom 1862 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eSporadic fluorescence was recorded on\r\ncuttings from limestone/siltstone stringers in the Paleocene and Cretaceous.\r\nTop Cretaceous had good shows on cuttings and sidewall core in the interval\r\n2300 - 2305 m, and two valid RFT pressure points indicated a gas gradient over\r\nthe interval.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eTop Brent Group, Ness Formation was\r\nencountered at 2597 m with an oil-filled Etive Formation from 2630 m to 2686 m.\r\nNo oil/water contact was found, but combined pressure data from the well and\r\nthree previous wells on the structure indicated a gas/oil contact at 2528 m.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eFour cores were cut from 2638 m in the\r\nEtive Formation to 2692.5 m, a few meters into the underlying Drake Formation. One\r\nRFT oil sample of good quality was taken at 2633 m.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"379","properties":{"OBJECTID":379,"wlbNpdidWellbore":384,"wlbName":"30/7-1","wlbHistory":"\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 30/7-1 was drilled in the eastern\r\npart of the East Shetland Basin in the North Sea. The well location is due west\r\nof the Oseberg Field and ca 3.5 km from the UK Border. The primary objective was\r\nto investigate structural closure at Eocene and Paleocene with possible sand\r\ndevelopment.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 30/7-1 was drilled with the\r\nsemi-submersible installation Polyglomar Driller. Polyglomar Driller was\r\naccepted in Verdal on June 28, and left for its first location on June 30, 1975\r\nat 1500 hrs. The rig was on location ready to spud on July 4, after a period of\r\n4 days for movement to location and for anchoring. During the drilling of the\r\n36" hole the drilling template tilted and the entire assembly had to be\r\npicked up. The rig was moved 50 ft due east and a new spudding attempt was made\r\non July 5, 1975. Drilling then proceeded without significant problems to 1007 m,\r\nwhich became TD of the well. While pulling out of the hole to set the 13\r\n3/8" casing the pipe stuck in the hole with the bit at 420 m. Numerous\r\nattempts to free the pipe were unsuccessful and it was decided to abandon the\r\nwell. The well was drilled with seawater/sweeps and gel from surface to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe penetrated sediments are interpreted\r\nas recent to Miocene in age.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo logs were run in the well. No cores\r\nwere cut and no wire line fluid samples were taken. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eDuring abandonment the drilling template was\r\nfound to be stuck and the attempts to recover it were unsuccessful. Divers were\r\njumped to inspect the drilling template and they reported the template had sunk\r\n10 ft below the sea bed. Permission was obtained to fill the cavity above the\r\nba","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"380","properties":{"OBJECTID":380,"wlbNpdidWellbore":385,"wlbName":"30/7-2","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 30/7-2 was drilled from a location\r\n150 ft (46 m) east of well 30/7-1, which was junked for technical reasons. The\r\nwell is located in the eastern part of the East Shetland Basin in the North\r\nSea. The well location is due west of the Oseberg Field and ca 3.5 km from the\r\nUK Border. The primary objective was to investigate structural closure at\r\nEocene and Paleocene with possible sand development.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell was spudded with the semi-submersible\r\ninstallation on 6 August 1975. While drilling the 36" hole at 167 m, the\r\ndrill string stuck. After several unsuccessful attempts to free the pipe, a\r\nstring shot was run and the hole was plugged. The well was re-spudded on 9\r\nAugust 9 after having moved the rig 200 ft (61 m) south-southeast. From 28\r\nAugust up to 10 September operations were more or less suspended at a depth\r\nbetween 991 and 1001 m due to technical problems with the BOP. The well was\r\ndrilled with gel/seawater mud down to 485 m, with seawater/gel and Drispac from\r\n485 m to 1001 m, and with seawater/gel/Drispac and Lignosulfonate (Unical) from\r\n1001 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eTwo minor shows were reported from Late\r\nEocene. The first, at 1226 m, is a sandstone with patchy yellow to whitish fair\r\nto weak fluorescence with a medium to slow cut. There was no visible oil stain\r\non the sample. The second, in a thin sandstone stringer, at 1525 m, gave a dull\r\ngold fluorescence with a slow streaming cut. At approximately 1700 a thin\r\nsandstone gave a gold fluorescence and a white, milky, streaming cut. The\r\nsamples had a slight oil stain. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well penetrated the Frigg Formation\r\nfrom 1748 to 1909m. It was hydrocarbon bearing with a gas/oil contact at 1762.8\r\nm and an oil/water contac","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"381","properties":{"OBJECTID":381,"wlbNpdidWellbore":386,"wlbName":"30/7-3","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 30/7-3 was drilled in the Fensal\r\nsub-basin south-southeast of the Hild Discovery and north of the Odin\r\nDiscovery.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe main objective of the well was to\r\ntest a mapped seismic anomaly below the "Ml" marker, prognosed to be\r\na possible porous carbonate development at Cenomanian level. The location of\r\nthe well gave a test of the anomaly on the western edge, according to the\r\nseismic mapping. Secondary objectives were possible Early Cretaceous\r\nsand/limestone pinch-outs and Late Jurassic sands.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well 30/7-3 was spudded with the\r\nsemi-submersible installation Polyglomar Driller on 6 August 1976 and drilled\r\nto TD at 4044 m in the Early Cretaceous (Albian - Aptian) Cromer Knoll Group.\r\nWhen drilling the 12" hole at 3001 m, a leak was discovered in the\r\nwellhead. A groove was cut in the sealing area between the wellhead and the\r\ncollet connector. A wellhead extension was run in the damaged wellhead with\r\nfour o-rings as seal towards the original wellhead. The drilling was continued\r\nand 9 5/8"casing was set at 3782 m. While drilling 8-3/8" hole at\r\n4044 m circulation was lost. When the mud weight was reduced in an attempt to\r\nre-establish circulation the well started to flow. A barite plug was set at\r\nbottom, and this finally stabilized the well. The well was drilled with\r\nfreshwater gel to 700 m and with lignosulphonate mud from 700 m to TD. \u003c/p\u003e\r\n\r\n\u003cp\u003eA comparison of the results from the\r\nseismic velocity survey and the seismic interpretations identify the interval\r\nbetween 3795 m and 3918 m as the target seismic anomaly. In this interval a\r\nsequence of limestone, marlstone and shale was found. The limestone is composed\r\nof mainly calcite with recognisable coccoliths. In the lower part minor\r\nterrigenous components of quartz sand and silt, and mica flakes were\r\nencountered. In places the limestone became very argillaceous grading to\r\nmarlstone and shale. No visible porosity or any hydrocarbon s","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"382","properties":{"OBJECTID":382,"wlbNpdidWellbore":387,"wlbName":"30/7-4","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 30/7-4 is located in the eastern\r\npart of the East Shetland Basin in the North Sea. The well location is due west\r\nof the Oseberg Field and ca 2.5 km from the UK Border. The main objective of\r\nthe well was to test Middle and Early Jurassic sandstones (Brent Group and\r\nStatfjord Formation) Secondary objectives were possible lower Cretaceous\r\ncarbonate development, and possible Late Jurassic sandstones.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 30/7-4 was spudded with the\r\nsemi-submersible installation Polyglomar Drilling on 25 January 1977. A 17\r\n1/2" pilot hole was drilled to 192 m. The operation had to be suspended\r\nfor two days due to bad weather. When the operation was continued, the 17\r\n1/2" pilot hole could not be found and a new 36" hole was drilled. The\r\n30" casing was set and cemented at 193 m. The weather conditions made it\r\nnecessary to set piggy backs on five anchors. A 17 1/2" hole was drilled\r\nto 778 m in assumed Miocene sediments. This was the planned setting depth for\r\nthe 20" casing. While reaming out the 17 1/2" hole to 26" prior\r\nto running 20" casing, the drill string parted. An overshot was worked\r\nover the fish but attempts to pull the fish were unsuccessful. The string was\r\nbacked off at 538 m in the x-over above the overshot and the hole was given up.\r\nThe well was drilled with seawater and gel.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo cores were cut, no logs were run, and\r\nno wire line fluid samples were taken.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was permanently abandoned on 5\r\nFebruary as a junk well and the rig was prepared for spudding replacement well\r\n30/7-5.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eTesting\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo drill stem test ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"383","properties":{"OBJECTID":383,"wlbNpdidWellbore":388,"wlbName":"30/7-5","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 30/7-5 was a replacement of the well\r\n30/7-4 which was lost due to "twist off" of the drill pipe. The well is\r\nlocated in the eastern part of the East Shetland Basin in the North Sea. The\r\nwell location is due west of the Oseberg Field and ca 2.5 km from the UK\r\nBorder. The main objective of the well was to test Middle and Early Jurassic sandstones\r\n(Brent Group and Statfjord Formation) Secondary objectives were possible lower\r\nCretaceous carbonate development, and possible Late Jurassic sandstones.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe semi-submersible installation\r\nPolyglomar Drilling was skidded over from the junked 30/7-4 well to the\r\nposition for 30/7-5 by regulating the length of the anchor chains. Well 30/7-5 was\r\nspudded with on 5 February 1977 and drilled the 26" section to TD at 805 m\r\nin Miocene sediments. When running the 20" casing, the string parted and\r\n18 joints of casing were left in the hole. Attempts to catch the fish failed\r\nand the well was given up. The well was drilled with seawater and gel.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo cores were cut, no logs were run, and\r\nno wire line fluid samples were taken.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was permanently abandoned on 13\r\nFebruary 1977 as a junk well, and the rig was prepared for spudding replacement\r\nwell 30/7-6.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eTesting\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo drill stem test was performed.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"384","properties":{"OBJECTID":384,"wlbNpdidWellbore":389,"wlbName":"30/7-6","wlbHistory":"\u003chtml\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 30/7-6 was drilled on the East\r\nShetland Basin in the North Sea close to the UK border. It was drilled as\r\nreplacement well for wells 30/7-4 and 30/7-5, which were both junked for\r\ntechnical reasons. Well 30/7-6 (Phase I) was planned to be suspended after setting\r\nthe 9-5/8" casing at ca 3800 m. The well would then be re-entered as\r\n30/7-6 R (Phase II) and drilled to a TD of ca. 5000 meters employing the\r\n11" 1000 bar BOP system. The main objective was Middle Jurassic\r\nsandstones, and this was planned to be penetrated in the re-entry. The exploration\r\ntargets in the 30/7-6 well were the secondary ones: possible lower Cretaceous\r\ncarbonate development, and possible Late Jurassic sandstones. The\r\nhydrocarbon-bearing Eocene sands (Frigg Formation) tested by the 30/7-2 well\r\nwere also expected to be encountered within the same structural closure by this\r\nwell. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 30/7-6 was spudded with the semi-submersible\r\ninstallation Polyglomar Driller on 15 February 1977. At 3784 m, on April 14, a\r\nmassive gas kick occurred and circulation was lost. The well was killed and\r\nplugged back into the 13 3/8" casing. A sidetrack was kicked off from 2619\r\nm. The sidetrack proceeded with the 12 1/4" hole to 3252 m and the 8\r\n3/8" hole to 3711 m. A 7" liner was set down to 3707. The cement\r\nflash set around the running string for the liner and 18 days were spent\r\ncleaning out the hole. At this point, the well was plugged back and suspended. The\r\nwell was drilled with a gel/lignosulphonate mud system.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe top of the Eocene sands were\r\npenetrated at 1783.5 m and were found to be water wet. This agrees with the\r\nobservation made in 30/7-2, in which the oil water contact was defined at 1783\r\nm. No res","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"385","properties":{"OBJECTID":385,"wlbNpdidWellbore":390,"wlbName":"30/7-7","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThe main objective of the well was to\r\ntest the SE prospect on the 30/7 block. The objective of the well was to test\r\npossible sandstone reservoirs of Jurassic age, which were predicted to occur-in\r\na large structure (150 km2) at the Kimmerian unconformity) located on the\r\neastern flank of the Viking basin. The specific targets were possible\r\nturbiditic sandstone deposits within a thick Late Jurassic sequence, Middle\r\nJurassic Brent Formation sandstones, and Early Jurassic Statfjord Formation\r\nsandstones. The well was planned to penetrate 50 m into the Statfjord Formation\r\nto approximately 5250 m. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe well is Reference Well for the Cook\r\nFormation.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well 30/7-7 was drilled between\r\nDecember 16th 1978 and May 30th 1979 with the rig Treasure Seeker. It reached\r\nTD at 5127 m in the Early Jurassic/Late Triassic Statfjord Formation. 34.5% of\r\nthe total rig time was lost time due to fishing, waiting on weather, waiting\r\nfor replacement of equipment, and hole problems. The problem that had most\r\nserious consequences for the geological program occurred while reaming from\r\n5114 m to 5125 m where the string got stuck. After 9.5 days of fishing for the\r\ndrill string it was finally backed of at 4804 m. At this point it was decided to\r\nabandon the well leaving the fish in the hole. Before this happened the well\r\nhad been logged down to 5122 m, but the fish made it impossible to test the\r\nStatfjord Formation sandstone. The well was drilled with Seawater/gel/hi-vis\r\npills spotting LCM pills as needed down to 763 m and with a\r\nSpersene/XP20/Drispac mud with 0 % to 4% oil and LCM pills as needed from 763 m\r\nto TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eSandstone levels interbedded with shales\r\nwere encountered below 2187 m in the Tertiary. They were mainly developed\r\nbetween 2216 and 2320 m. Some calcareous levels in the Maastrichtian limestones\r\nbetween 2531 and 2575 m could be considered as reservoirs. Limestone stringers\r\nin the Turonian calcareous section from","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"386","properties":{"OBJECTID":386,"wlbNpdidWellbore":391,"wlbName":"30/10-1","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 30/10-1 is located on the Northern\r\napex of the Frigg field. The well was drilled as a wildcat, primarily to\r\nevaluate the Lower Eocene sand ("Frigg Field Clastic Tongue") in the\r\narea. Secondly, the well should evaluate the Paleocene sands and the Late\r\nCretaceous limestone. The plan was to set the 9 5/8 inch casing in the top of a\r\nhigh-pressure zone (Cretaceous Shale) prior to moving the rig Saipem Due to\r\nanother location. The hole should then be re-entered with another rig and drill\r\ndeeper to evaluate a deep-seated structural closure. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 30/10-1 was spudded with the vessel\r\nSaipem Due on 5 May 1973 and drilled to TD at 2917 m in Late Cretaceous\r\n(Maastrichtian) shale. Initial drilling from the sea floor to 1067 m was with\r\nseawater and gel. Below 1067 m a fresh water Spersene XP 20 (lignosulphonate)\r\nmud system was used. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe thickness of the pay section of the\r\nFrigg Clastic Tongue (Primary objective) was disappointing in that it was very\r\nthin. A green shale unit replaced the expected pay section. Formation interval\r\ntest and logs indicate that approximately 4 m of the Frigg Clastic sand\r\ncontained gas and approximately 6 m could possibly be oil bearing. No other\r\ngood hydrocarbon shows were encountered below the Frigg Clastic Tongue. in the rogaland Group almost\r\n200 m of sand were present, however, the sand was void of hydrocarbons,\r\nwith the exception of some scattered fluorescence in the upper portion. Five\r\ncores were cut in the Frigg sand in the interval 1974 m to 2010 m. No sidewall\r\ncores were taken. Four Formation Interval Tests (FITs) were taken in the Frigg\r\nsand. FIT No 1 at 1960.5 m recovered, 29 cubic feet of gas, 5 litres water and\r\n0.5 litres mud. FIT No. 2 at 1989.5 m recovered 10 litres water. FIT No. 3 at\r\n1974.5 m recovered 7 litres liquid (mud and water) and 100 cc oil. FIT No. 4 at\r\n1966 m recovered 6.5 cubic feet gas, 2.25 litres oil, 300 cc mud, and 4.75\r\nlitres of water. Oil g","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"387","properties":{"OBJECTID":387,"wlbNpdidWellbore":392,"wlbName":"30/10-2","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 30/10-2 was the discovery well for\r\nthe Odin field, located North of the Frigg Field. The primary objective of the\r\nwell were to evaluate the Early Eocene sands ("Frigg Field Clastic\r\nTongue") predicted at 1954 m. Secondary objectives were to evaluate the\r\nPaleocene sands and the Danian / Late Cretaceous limestone prognosed from ca\r\n2187 m to ca 2713 m.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eExploration well 30/10 2 was spudded with\r\nthe semi-submersible installation Drillmaster on 24 December 1973 and drilled\r\nto TD at 2755 m in Late Cretaceous (Maastrichtian) Hardråde Formation. The mud\r\nprogramme used was a seawater/Lignosulphonate system. Some drilling problems\r\nwere encountered due to shale cavings. After drilling to 2026 m it was\r\nnecessary to condition the hole several days due to caving shales. While\r\ndrilling at 2147 m three cones were lost in the hole and when attempting to\r\nrecover these, six feet of the bottom drilling string was left in the hole. The\r\nfish was recovered after several attempts. Later after setting 9 5/8"\r\ncasing the hole was drilled to TD with some minor shale caving problems.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe Late Cretaceous consisted primarily\r\nof interbedded tight micritic limestone and shale. No reservoir beds were\r\npresent and no significant shows were recorded. However, traces of dead oil\r\nwere noted between 2722 m and 2743 m (Ekofisk Formation). The Danian section\r\nconsisted of detrital and skeletal limestone. No reservoir beds were noted and\r\nno shows recorded. The Paleocene contained 235 m of potential sandstone\r\nreservoirs. The sands were water wet and no significant shows were recorded.\r\nHowever traces of dead oil was again noted in an upper massive sand and in\r\nsilty shales (Lista Formation) from 2457 m to 2472 m and from 2527 m to 2594 m.\r\nThe Eocene section contained a good sand reservoir (Frigg Formation) from 1997\r\nm to 2067 m. The formation was gas-filled down to 2048 m. The sand is white,\r\nmedium to coarse grained, fine to ver","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"388","properties":{"OBJECTID":388,"wlbNpdidWellbore":393,"wlbName":"30/10-3","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 30/10-3 was drilled on the Odin\r\nDiscovery just north of the Frigg area. The main objective was to evaluate the\r\nEarly Eocene sand ("Frigg Field Clastic Tongue") and appraise the\r\n30/10-2 Odin gas Discovery.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eAppraisal well 30/10-3 well was spudded\r\nwith the semi-submersible installation Drillmaster on 8 August 1974 and drilled\r\nto TD at 2255 m in sands of the Paleocene Hermod Formation. Some anchor\r\nproblems were experienced due to the sandy sea floor; otherwise no drilling\r\nproblems were encountered during the operations. The mud used was a seawater,\r\nlignosulphonate system.\u003c/p\u003e\r\n\r\n\u003cp\u003eCuttings from 177 m to 704 m\r\n(Pliocene-Miocene undifferentiated) consisted of sand and shells (coquina).\r\nFrom 704 m to 1213 m (Oligocene) the section consisted of sand, coquina and\r\ntraces of lignite between 780 m and 1213 m. From 1213 m to 1594 m the section\r\nis grey shale with stringers of thin micritic limestone. From 1594 m to 1823 m\r\nthe section is predominantly grey shale with minor traces of micritic\r\nlimestone. From 1824 m to 2030 m a green shale unit is present. At 2030 m (Top\r\nFrigg Clastic Tongue) the lithology changed to sand and continued to a depth of\r\n2073 m. From 2073 m to 2182 m the section consisted of red brown shales and\r\nsands. From 2182 m to TD (Paleocene) the section is predominantly sand with\r\nsome thin grey shales. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe Paleocene sand was void of\r\nhydrocarbon shows. The Frigg Clastic Tongue was 43 m thick. Logs and cores\r\nindicated approximately 24 m of this interval contained oil and gas down to an\r\noil-water contact at 2054 m. Net pay was 18 m of which 14 m was good clean gas\r\nsand and 4 m oil sand. \u003c/p\u003e\r\n\r\n\u003cp\u003eSix cores were cut from 2010 m in the\r\n"Green shale unit" down to 2064 m, 34 m into the Frigg sand. Eight\r\nFormation Interval Test (FIT) fluid samples were recovered from four different\r\ndepths in the Frigg sand. A sample from 2068.1 m 9.75 l water and 0.5 l mud; a\r\nsample from 2052.8 m","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"389","properties":{"OBJECTID":389,"wlbNpdidWellbore":394,"wlbName":"30/10-4","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 30/10 4 was drilled on the northern\r\ntip of the Frigg Field. Its main purpose was to explore a deep-seated closure\r\nat Middle Jurassic level. This was a secondary target in the 30/10-1 well, but\r\nit was not reached in this well, which was terminated in the Late Cretaceous\r\ndue to high-pressure problems.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 30/10-4 was spudded with the\r\nsemi-submersible installation Neptune 7 on 11 September 1974 and drilled to TD\r\nat 758 m. At this point the drill string was lost in the hole. Fishing was\r\nunsuccessful and the well was plugged back and junked. The well was abandoned\r\non 25 September 1974.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was performed\u003c/p\u003e\r\n\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"390","properties":{"OBJECTID":390,"wlbNpdidWellbore":395,"wlbName":"30/10-5","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 30/10-5 was drilled on the northern\r\ntip of the Frigg Field. Its main purpose was to explore a deep-seated closure\r\nat Middle Jurassic level. This structure was targeted already in the 30/10-1\r\nand 30/10-4 wells, but it was not reached because well 30/10-1 was terminated in the Late\r\nCretaceous due to high-pressure problems and well 30/10-4 became junked in the Miocene due to an unrecoverable fish. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eExploration well 30/10-5 was spudded with\r\nthe semi-submersible steel installation Neptune 7 on 25 August 1974 and drilled\r\nto TD at 5185 m in the Late Triassic Hegre Group. Reaming of the 12 1/4"\r\nhole to17 1/2" for setting the 13 3/8" casing was delayed due to\r\nseveral twist-offs, junk in hole, pod trouble and weather. After setting the13\r\n3/8" casing drilling was resumed. At 2943 m, lost circulation was\r\nencountered, however; after setting a cement plug, drilling was continued\r\nwithout difficulties. Drilling from the sea floor to 747 m was with seawater\r\nand gel. Below 747 m a fresh-water Spersene XP 20 (lignosulphonate) mud system\r\nwas used.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe Oligocene section consisted entirely\r\nof siltstone and clay. The Eocene, section contained a sandstone reservoir\r\n(Frigg Formation, first informally termed "Frigg Clastic Tongue")\r\nfrom 1964 m to 2150 m. Good gas shows were present from 1965 m to 1974 m and\r\ngood oil shows from 1974 m to 1978 m. Below 1978 m the section was water wet.\r\nThe Rogaland Group contained 159 m of potential sandstone reservoirs but no shows\r\nwere encountered. The Danian consisted of silty limestone and dark grey shale.\r\nThe Late Cretaceous consisted primarily of interbeds of tight micritic\r\nlimestone, marl and shale. Numerous gas shows were noted in limestone stringers\r\nin the uppermost part of this section. The limestone section between 2917 m and\r\n2943 m was sandy and contained some gas. A second zone between 3628 m and 3534\r\nm also contained some gas. Log analysis indicated","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"391","properties":{"OBJECTID":391,"wlbNpdidWellbore":396,"wlbName":"30/11-1","wlbHistory":"\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 30/11-1 was drilled in the Fensal\r\nSub-basin between the Frigg area and the Stord Basin in the North Sea. The\r\nprimary objective was the Eocene Frigg sand, which was gas bearing in the\r\nFrigg, East Frigg, Northeast Frigg, Odin and Heimdal fields to the west and\r\nsouth. Secondary objectives were sands of Paleocene age.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 30/11-1 was spudded with the\r\nsemi-submersible installation Ocean Voyager on 5 February 1975 and drilled to\r\nTD at 2682 m in the Late Shetland Group. No significant problem was encountered\r\nin the operations. The well was drilled with seawater and viscous slugs down to\r\n469 m, and with a lignosulphonate mud from 469 m to TD. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eFour zones of interest were encountered\r\nin the well, namely the Frigg sand, Cod sand, Danian sand and Late Cretaceous\r\nlimestone. All four intervals were interpreted as being water bearing. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eFrom petrophysical analysis the Frigg\r\nFormation had 68 m net sand (N/G = 0.9) in the interval 1952.5 to 2026.9 m. The\r\naverage porosity is 32%. The "Cod sand" (Sele and Hermod formations)\r\nfrom 2211.0 to 2354.3 m had 102 m net sand (N/G = 0.71) with 36% average\r\nporosity. The "Danian sand" (Ty Formation) from 2586.8 to 2638.7 m) had\r\n43 m net sand (N/G = 0.83) with 25% average porosity. The Late Cretaceous\r\nlimestone was described as shaly in parts, but clean limestone intervals had\r\nporosities from 4.5 to 7%. Gas readings were low in the well, and the only oil\r\nshow described was "very, very faint solvent cut fluorescence" in the\r\nFrigg Sand.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eTwo cores were cut in the interval 1978.2\r\nto 1994.9 m. No fluid sample was taken.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBod","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"392","properties":{"OBJECTID":392,"wlbNpdidWellbore":397,"wlbName":"30/11-2","wlbHistory":"\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 30/11-2 was drilled on the Bjørgvin\r\nArch between the Stord Basin and the Frigg Field in the North Sea. The primary objective\r\nwas a potential stratigraphic trap, formed by a shale-out of the Early Eocene\r\n"Frigg Sand" equivalent. Secondary objectives were sand bodies in the\r\nunder-lying Paleocene (Cod and Danian Sands).\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 30/11-2 was spudded with the\r\nsemi-submersible installation Ocean Vanguard on 18 March 1975 and drilled to TD\r\nat 2590 m in the Late Cretaceous Shetland Gp. A shallow gas incident occurred\r\nat 343 m where the total mud gas increased to more than 30% for 5 minutes. The\r\nmud weight was increased to 490 psi. No further significant problem was\r\nencountered in the operations. The well was drilled with seawater and viscous slugs\r\ndown to 215 m, with H921 Polymer/lignosulphonate/Gel and Ferrobar weighting\r\nmaterial from 215 m to 1158 m, and with Dextrid/gel/lignosulphonate and Ferrobar\r\nweighting material from 1158 m to TD. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAll targets including the Frigg sand were\r\nwater bearing. The Frigg Formation was encountered at 2052 m and was 86 m\r\nthick. Based on petrophysical analysis it contain 58 m net sand (N/G = 0.69)\r\nwith 33% average porosity. The Cod and Danian Sands were absent, or represented\r\nonly by thin sandstone streaks and tight siltstones. Apart from the shallow gas,\r\nall gas readings were low throughout the well. The only oil show described was\r\n"a very faint solvent cut fluorescence" on a sidewall core from\r\n2120.2 m in the Frigg sand.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo cores were cut and no fluid sample was\r\ntaken.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was permanently abandoned on 16\r\nApril 1975 as a dry well.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"393","properties":{"OBJECTID":393,"wlbNpdidWellbore":398,"wlbName":"31/2-1","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 31/2-1 is the Troll West gas and oil\r\nDiscovery well. The purpose of the well was to establish the basic stratigraphy\r\nin the area, and to evaluate the prospectivity of the Jurassic sequence. The\r\nstructure is formed by a tilted Jurassic fault block on the Sogn Spur High\r\nbetween the North Viking Graben and the Horda Basin. A migration path from the\r\nViking Graben kitchen area is provided by monoclinal fault blocks. The most\r\ndominant characteristic of the structure was the presence of a\r\n"flatspot", which was believed to be associated with a present\r\nhydrocarbon/water contact. Sealing of the potential Jurassic reservoir is\r\nprovided by Cretaceous and Paleocene Claystones, overlying the reservoir\r\nsandstones.\u003c/p\u003e\r\n\r\n\u003cp\u003e \u003c/p\u003e\r\n\r\n\u003cp\u003eThe well is Type Well for the Johansen,\r\nKrossfjord, Fensfjord, and the Sognefjord Formations, and Reference Well for\r\nthe Amundsen, Cook, and Drake Formations.\u003c/p\u003e\r\n\r\n\u003cp\u003e \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 31/2-1 was spudded with the\r\nsemi-submersible installation Borgny Dolphin on 17 July 1979 and drilled to TD\r\nat 2433 m in the Late Triassic Hegre Group. Severe problems with setting the\r\n30" casing led to abandoning of the first hole and re-spudding on 24 July,\r\n50 m to the south of the original spud position. The well was drilled with gel\r\npolymer down to 793 m, and with gypsum/lignosulphonate mud from 793 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well 31/2-1 proved the existence of a\r\nLate - Middle Jurassic gas bearing reservoir sequence in the Flathead A\r\nstructure (block 31/2). A gross commercial gas column of 134.5 metres with top\r\nat 1439.5 m was encountered in good-moderate quality coastal - shallow marine\r\nsands. Good oil shows with oil bleeding from cores were encountered from 1567 m\r\nto 1597 m, below the gas. It is possible that both a gas-oil contact and an\r\noil-water contact occur in this zone, however, data available suggested tight\r\nformation. From the pressure data the plausible interpretation is t","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"394","properties":{"OBJECTID":394,"wlbNpdidWellbore":399,"wlbName":"31/2-6","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 31/2-6 is located in a fault block\r\nnorth-east on the main Troll structure, approximately 8 km NNE of 31/2-3. The\r\nmain objective of the well was to test the north-eastern margin of the Troll\r\nstructure and to prove hydrocarbon communication between block 31/2 and 31/3.\r\nThe well location was picked to test the oil zone in a good sand reservoir. A\r\nsecond objective was to get reliable geologic tie to the seismic reflectors to\r\nallow for accurate lateral extrapolation of well data. Planned TD was 2500 m in\r\nTriassic sediments. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe well is Reference Well for the Sele\r\nFormation.\u003c/p\u003e\r\n\r\n\u003cp\u003e \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eAppraisal well 31/2-6 was spudded with\r\nthe semi-submersible installation Borgny Dolphin on and drilled to TD at 1760 m\r\nin the Late Jurassic Formation. The 9 5/8" casing collapsed at 771 m and\r\nwas cut and retrieved from 760 m. As a result of this, well 31/2-6 was not\r\ndeepened to the Triassic. The well was drilled with seawater gel down to 614 m\r\nand with KCl polymer mud from 614 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 31/2-6 proved a similar hydrocarbon\r\naccumulation in this northern fault block area to that of the main field\r\naccumulation tested by wells 31/2-1,2,3 and 4. The well encountered the\r\nSognefjord Formation at 1492 m. The Formation held a 79.4 m gross gas column\r\nunderlain by a 10.3 m oil column. The GOC at 1571.4 m and the OWC was at 1582.2\r\nm. Well 31/2-6 confirmed the overall interpretation of the flatspot as a direct\r\nhydrocarbon indicator. Oils shows were recorded on cores from 1504 m to 1601 m.\r\nIn addition, cuttings gave patchy shows in the interval from 1710 m to 1758 m.\r\nSidewall cores from this interval did not confirm shows in the latter interval.\u003c/p\u003e\r\n\r\n\u003cp\u003eCoring commenced at 1504.4 m and\r\nterminated at 1632.05 m, within the Sognefjord Formation. Thus 127.65 m of core\r\nwas cut from which 123.65 m (97%) was recovered. An RFT gas sample was taken at\r\n1518 m as a backup until samples could be obtained from the subs","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"395","properties":{"OBJECTID":395,"wlbNpdidWellbore":400,"wlbName":"31/4-1","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 31/4-1 is located on the Brage Horst\r\nbetween the Oseberg and Troll Fields in the Northern North Sea. The primary\r\nobjective was Middle Jurassic sandstones of the Brent Formation. A "flat-spot"\r\nwas seen on the seismic sections and tentatively interpreted to represent a gas\r\nfluid contact in these sandstones. A secondary objective was sandstones in the Early\r\nJurassic Statfjord Formation. Sandstone intervals of upper Early Jurassic age\r\n(Dunlin Formation) and of Triassic age (Hegre Group), were also expected to be\r\npenetrated, but were not considered to be prospective. The well was planned to\r\nbe drilled to a depth of 2930 m RKB (+/- 90 m), 100 m into the Triassic.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 31/4-1 was spudded with the semi-submersible\r\ninstallation Norskald on 9 September 1979 and drilled to TD at 1000 m in Late\r\nOligocene - Miocene sediments of the Hordaland Group. \u003c/p\u003e\r\n\r\n\u003cp\u003eNone of the objectives were tested due to\r\ntechnical problems; the well was plugged and abandoned due to lack of cement support\r\naround the 30" casing, experienced when landing the 20" casing. No\r\ncores were cut and no wire line fluid samples were taken.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 25 September 1979 as a junk well. The rig was moved over 100 - 150 m in a direction 213\r\ndegree N to spud replacement well 31/4-2.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was performed.\u003c/p\u003e\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"396","properties":{"OBJECTID":396,"wlbNpdidWellbore":401,"wlbName":"31/4-2","wlbHistory":"\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 31/4-2 is a replacement for junk\r\nwell 31/4-1. The well is located on the Brage Horst between the Oseberg and\r\nTroll Fields in the Northern North Sea. The primary objective was Middle\r\nJurassic sandstones of the Brent Formation. A "flat-spot" was seen on\r\nthe seismic sections and tentatively interpreted to represent a gas fluid\r\ncontact in these sandstones. A secondary objective was sandstones in the Early\r\nJurassic Statfjord Formation. Sandstone intervals of upper Early Jurassic age\r\n(Dunlin Formation) and of Triassic age (Hegre Group), were also expected to be\r\npenetrated, but were not considered to be prospective. The well was planned to\r\nbe drilled to a depth of 2930 m RKB (+/- 90 m), ca 100 m into the Triassic.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 31/4-2 was spudded with the\r\nsemi-submersible installation Norskald on 26 September 1979 and drilled to TD\r\nat 2900 m in the Triassic Lunde Formation. There were some problems with\r\nkeeping position and anchor movements in rough weather, but otherwise\r\noperations went forth without significant problems. The well was drilled with Seawater\r\nand pre-hydrated bentonite down to 990 m, with Seawater/Drispac/pre-hydrated\r\nbentonite from 990 m to 1712 m, and with seawater/prehydrated\r\nbentonite/ligcon/Unical mud from 1712 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eGood oil shows were recorded on sidewall\r\ncores from thin sandstone stringers at 2061 to 2069 m in the upper part of the\r\nShetland Group. The well penetrated top Draupne Formation at 2146 m and top\r\nHeather Formation at 2171 m. The Heather Formation contained a 49 m thick very\r\nfine to silty water-bearing sandstone interval from 2190 to 2239 m. The well\r\npenetrated two hydrocarbon bearing sandstone intervals at 2325 to 2329 m and\r\n2344.5 to 2354 m within a 29 m thick Mi","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"397","properties":{"OBJECTID":397,"wlbNpdidWellbore":402,"wlbName":"31/4-3","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 31/4-3 was drilled on the Bjørgvin\r\nArch in the North Sea, east of the Oseberg main field. Near-by well 31/4-2 on\r\nthe southern part of the Brage Horst had recently found live oil and gas in\r\nsmall quantities in the Brent Group. The primary objectives were sandstones\r\nwithin the Early Jurassic Dunlin and Statfjord Formation. They were thought to\r\nbe separate reservoirs with different hydrocarbon/water contacts. A secondary\r\nobjective was to penetrate a deep seismic marker assumed to be a Paleozoic\r\nunconformity. Accumulation of hydrocarbons in Early Triassic and pre-Triassic\r\nsandstones were considered possible if adequate seal and source rocks were\r\npresent. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 31/4-3 was spudded with the\r\nsemi-submersible installation Treasure Seeker on 24 December 1979 and drilled\r\nto TD at 4981 m in rocks of Triassic/Permian age. The well was drilled with\r\nseawater and hi-vis sweeps down to 906 m, with XP-20/Spersene/Drispac mud from\r\n906 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eTwo separate hydrocarbon-bearing\r\nsandstone intervals were encountered in the Late Jurassic Heather Formation. The\r\nOxfordian to Kimmeridgian "Intra Heather Sand I" from 2018 m to 2082\r\nm had gas down to a gas/oil contact at ca 2035 m and oil down-to 2048 m. The\r\nsection below 2048 had silty to shaley sand with 82% water saturation. The OWC\r\ncould be somewhere in this section between 2048 and 2054 m. The Callovian "Intra\r\nHeather Sand II" (Fensfjord Formation) from 2136 to 2246 m had oil (57.7%\r\naverage water saturation) down to a possible OWC at 2172. This section was a\r\nsilty/shaley sand and the net pay was 24 m. Below this the well penetrated 45 m\r\nof Middle Jurassic Brent Group sandstones, a 291 m thick Dunlin Group with sandstone\r\nin the Cook Formationa","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"398","properties":{"OBJECTID":398,"wlbNpdidWellbore":403,"wlbName":"31/4-5","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 31/4-5 was drilled on the\r\n31/4-3 Discovery on the Bjørgvin Arch in the northern North Sea. The primary\r\nobjective was to test "Intra Heather Formation" sands on the "B\r\nstructure" in a crestal position, up dip from the discovery well 31/4-3.\u003c/span\u003e\u003cspan\r\nlang=EN-GB\u003e \u003c/span\u003e\u003cspan lang=EN-GB\u003eThe well was planned to delineate known\r\nhydrocarbons in the "Intra Heather Sand I" (Sognefjord Formation) and\r\nto test the prospect for additional up dip oil and gas reserves in the "Intra\r\nHeather Sand II" (Fensfjord Formation). The well was planned to enter the\r\n"Intra Heather Sand I" reservoir approximately 20 m below the OWC in\r\norder to provide evidence of the extent of the reservoir. The lower oil bearing\r\nzone ("Intra Heather Sand II") was prognosed approximately 20 m\r\nhigher than in well 31/4-3 and significant amounts of up dip oil were thought\r\nto exist. The Brent, Dunlin and Statfjord Groups were secondary objectives,\r\npossibly prospective in an up dip position.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 31/4-5 was spudded with the\r\nsemi-submersible installation Nortrym on 27 May 1981 and drilled to TD at 2930\r\nm in the Triassic Hegre Group. The well was drilled without significant\r\nproblems. It was drilled with seawater and hi-vis pills down to 926 m, with KCl\r\nmud from 926 m to 1966 m, and with a lignosulphonate/XC polymer/Drispac mud\r\nfrom 1966 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well penetrated the Sognefjord\r\nFormation at 2070 m and the Fensfjord Formation at 2104 m. The Sognefjord\r\nFormation was 8.5 m thick and water bearing, but with good oil shows. The\r\nFensfjord Formation was hydrocarbon bearing with a net sand of 60 m and a net\r\npay of 37 m. The oil/water contact was not possible to define exact","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"399","properties":{"OBJECTID":399,"wlbNpdidWellbore":404,"wlbName":"31/6-4","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 31/6-4 was drilled in the southern\r\npart of the Troll East gas province. The main purpose was to appraise and test\r\npossible oil and gas accumulations in sandstones of Late to Middle Jurassic\r\nage. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eAppraisal well 31/6-4 was spudded with\r\nthe semi-submersible installation Deepsea Bergen on 5 March 1984 and drilled to\r\nTD at 820 m in Eocene sediments. After setting of the 30" casing a 12\r\n1/4" pilot hole was drilled. When opening the pilot hole to 26" hole,\r\nthe hole holed kicked off from the pilot hole and deviated to 12.75 deg. at 662\r\nm. Because of the deviation it was decided to junk the well. The well was\r\ndrilled with spud mud.\u003c/p\u003e\r\n\r\n\u003cp\u003eNo cores were cut and no fluid samples\r\ntaken.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was junked and abandoned on 16\r\nMarch as a dry well.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was performed\u003c/p\u003e\r\n\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"400","properties":{"OBJECTID":400,"wlbNpdidWellbore":405,"wlbName":"33/5-2","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThe prime objective of the well 33/5-2\r\nwas to test a Late Jurassic sandstone reservoir.\u00A0 The Middle Jurassic Brent\r\nGroup and the Early Jurassic Statfjord Formation were considered secondary\r\nobjectives. The Late Jurassic (Early Kimmeridgian) sandstone was assumed to be\r\na continuation of the same deposits recorded at the Magnus Field and in the\r\nwells 211/8-1 and 211/13-3.\u00A0 These deposits constitute the oil reservoir at the\r\nMagnus Field and were also hydrocarbon bearing in 211/13-3. This objective was\r\nconsidered a high-risk prospect since the "Magnus Sandstone Member"\r\nhad previously not been recorded on this side of the 211/13- 33/5- (Makrell-)\r\nhorst. The Brent Group was expected to be as in the wells 211/13-2 and -6 where\r\nit is oil bearing.\u00A0 It was thought to be a typical shallow to marginal marine\r\nsandstone sequence, deposited during shoreline progradation. The location far\r\ndown flank from the crest of the closure was considered to make hydrocarbon\r\noccurrence in the 33/5-2 Brent Group less likely. This was also the case for\r\nthe Statfjord Formation.\u00A0 It was expected to consist of fine to coarse,\r\noccasionally pebbly sandstones with some shale interbeds of fluvial to marginal\r\nmarine origin. The well was planned to drill approximately 50 m into the\r\nStatfjord Formation with an expected total depth at 4525 m.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eA number of "pockmarks"\r\ntypically 40 m across and 2 m deep were seen in the northern and eastern part\r\nof the area of the well location. To get some more information about the\r\nuppermost meters of soil, seafloor sampling and analysis were conducted by\r\nIKU.\u00A0 The seabed was found to consist of a fine sand, normally firm with shell\r\nfragments, plastic, silty clay and below greyish green sand. \u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 33/5-2 was spudded with the\r\nsemi-submersible installation Nortrym on 31 July 1981 and drilled to a total\r\ndepth of 4520 m in the Triassic Lunde Formation. The well was drilled with\r\nsea","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"401","properties":{"OBJECTID":401,"wlbNpdidWellbore":406,"wlbName":"33/6-1","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 33/6-1 is located in the Marulk\r\nBasin northwest of the Snorre Field in the southeastern sector of block 33/6.\r\nThe location was selected on the crestal area of the most attractive feature in\r\nthe licence: a fault bounded, tilted block. The closure was considered\r\ndependent upon the sealing properties of the NE-SW fault to the south of the\r\nprospect. The primary objective of the well was to test the Middle-Early\r\nJurassic Brent-Statfjord reservoirs. Planned TD was in the Late Triassic Hegre\r\nGroup\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eExploration well 33/6-1 was spudded on\r\nApril 9, 1979 in 306 m water depth, the deepest drilling location to that date.\r\nSemi-submersible installation Fernstar was used to drill the well. Due to soft\r\nbottom conditions and problems with stabilizing the temporary guide base on the\r\nsea floor the well was re-spudded twice, the last and successful attempt on\r\nApril 15. The well reached TD at 3900 m in the Early Jurassic Statfjord\r\nFormation. The well was drilled with seawater and pre-hydrated bentonite down\r\n434 m, with seawater/HPD polymer/bentonite from 434 m to 695 m, with\r\nKCl/Dextrid/seawater from 695 m to 1690 m, and with lignosulphonate/fresh water\r\nfrom 1690 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe most significant horizons, the top of\r\nthe Paleocene Seismic Marker and top Cretaceous, came in 13 meters lower and\r\n37,5 meters higher than expected, respectively. The pre-Cretaceous section\r\ndeviated significantly from prognosis. This was caused by a very crude depth\r\nconversion model due to lack of well control in the area and a much thinner\r\nBrent thickness than prognosed. All pre-Cretaceous targets were found however.\r\nThe Late Kimmerian unconformity was encountered 133.5 m high to prognosis. The\r\nLate Jurassic shale was 65.5 m thick, 35 meters thicker than prognosed and\r\nconsisted of 30 m of Draupne Formation plus 35.5 m of Heather Formation. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe primary target Brent Group was\r\npenetrated at 3603 m, 97 meters higher than prognosed, and on","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"402","properties":{"OBJECTID":402,"wlbNpdidWellbore":407,"wlbName":"33/9-1","wlbHistory":"\u003chtml\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 33/9-1 was drilled on the Statfjord\r\nstructure. It was the first appraisal well on the structure after well 33/12-1\r\nhad discovered oil there in 1973-1974. The primary objective was to test\r\nsandstones in the Middle Jurassic Brent Group. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well is reference well for the\r\nAmundsen, Burton, Cook, Drake, Broom, Rannoch, Etive, Tarbert, Heather, and\r\nDraupne formations.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 33/9-1 was spudded with the semi-submersible\r\ninstallation Norskald on 2 April 1974 and drilled to TD at 3126 m in Late\r\nTriassic sediments of the Statfjord Group. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe target Middle Jurassic Brent Group,\r\nTarbert Formation came in at 2464 m and was oil-bearing down to the OWC at 2584\r\nm in the Etive Formation. The Brent reservoir has 145 m gross pay and 124 m net\r\noil pay. Porosities range from 13.0 to 35.9 percent with the overall average\r\nporosity being 25 percent. Average water saturation is 18 percent. Cores taken\r\nnear top of the reservoir showed porosities up to 37% and permeabilities as\r\nhigh as 4.1 darcy. The Statfjord Group sandstone was penetrated at 2923 m. Statfjord\r\nGroup sandstone was water wet as expected from the structural position of this\r\nwell. The sands, however, had very good reservoir qualities with average\r\nporosity of 22 percent as calculated from the CPI log.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eTwo cores were cut in the Tarbert\r\nFormation from 2469.2 to 2499.4 m with 18 m recovery (60%) of the total cored\r\ninterval. No fluid samples were taken on wire line.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was permanently abandoned on 4\r\nJune 1974 as an oil appraisal.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eTesting\u003c/s","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"403","properties":{"OBJECTID":403,"wlbNpdidWellbore":408,"wlbName":"33/9-2","wlbHistory":"\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 33/9-2 was drilled on the Statfjord\r\nstructure on Tampen Spur in the northern North Sea. The primary objective was\r\nto provide seismic velocity control for detailed field mapping and to provide\r\nadditional reservoir data for the Statfjord Field development.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 33/9-2 was spudded with\r\nthe semi-submersible installation Norskald on 27 August 1974 and drilled to 940\r\nm in Oligocene sediments of the Hordaland Formation. The well was abandoned at\r\nthis depth due to irreparable damage to the subsea equipment. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo cores were cut and no fluid sample was\r\ntaken.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was abandoned as a junk well on 14\r\nSeptember 1974. Replacement well 33/9-2 was initiated to fulfil the well\r\nobjectives.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eTesting\u003c/span\u003e\u003c/b\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo drill stem test was performed.\u003c/span\u003e\u003c/p\u003e\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"404","properties":{"OBJECTID":404,"wlbNpdidWellbore":409,"wlbName":"33/9-4","wlbHistory":"\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 33/9-4 was drilled on the Statfjord\r\nstructure on Tampen Spur in the northern North Sea. The primary objective was\r\nto test the northern extension of the Statfjord discovery in the Brent Group.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 33/9-4 was spudded with\r\nthe semi-submersible installation Norskald on 30 July 1975 and drilled to TD at\r\n3076 m in the Triassic Hegre Group. No significant problem was encountered in\r\nthe operations. The well was drilled with seawater and spud mud down to 488 m and\r\nwith Lignosulphonate mud from 488 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe objective Brent Group was encountered\r\nat 2554.5 meters, 33.9 meters high to prognosis. Measured core porosities in\r\nthe Brent Group averaged 26 percent. Horizontal liquid permeability ranged from\r\n0.05 to 1100.5 milliDarcy and averaged 2155 milliDarcy. The Brent Group was oil\r\nfilled down to the oil-water contact at 2611.5 m. This is 2 m deeper than on\r\nthe southern part of Statfjord Field and constitute an in-well gross oil column\r\nof 57 m of which 37 m was calculated as net reservoir with 25.4% average\r\nporosity and 24.2% average water saturation. Apart from shows in the oil\r\nbearing section an oil show was described on a sidewall core at 2618 m.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eContinuous coring was carried out from\r\nwithin the overlying Middle Jurassic shales through the base of the oil/water\r\ncontact in the Brent sands, from 2547.2 to 2612.5 meters. Of the 56.7 meters\r\ncut by nine cores, 50.7 meters (89 percent) was recovered. No fluid sample was\r\ntaken on wire line.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was permanently abandoned on 17\r\nSeptember as an oil appraisal well.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eTesting\u003c/span\u003e\u003c/b\u003e\u003cspan lang=EN-GB\u003e ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"405","properties":{"OBJECTID":405,"wlbNpdidWellbore":410,"wlbName":"33/9-5","wlbHistory":"\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 33/9-5 was drilled on the northern\r\npart of the Statfjord structure on Tampen Spur in the northern North Sea. The objective\r\nwas to appraise the northern extension of the Statfjord Field with the Brent\r\nGroup as primary target. The Brent Group had previously proved oil bearing in\r\nwells 33/9-3 and 33/9-4 on the northern part of the structure. The well was\r\npositioned to penetrate the upper Brent reservoir at 2522 m MSL, 62 meters\r\nabove the known field water level. The Statfjord Group was a secondary\r\nobjective.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 33/9-5 was spudded with\r\nthe semi-submersible installation\u00A0 Ross Rig on 27 October 1975 and drilled to\r\nTD at 3157 m in Late Triassic sediments of the Statfjord Group. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eTop Brent Group (Tarbert Formation) was\r\nencountered at 2605 m, 57.8 m low to prognosis. As with other Brent Group oil\r\nwells in the Statfjord Field, high total gas readings (70 000 ppm) were\r\nencountered when the reservoir was penetrated. Using the field pay cut off\r\nvalue of 65% water saturation, the oil/water contact depth as measured from the\r\nCPI log is 2616.4 m (2591.4\u00A0 MSL), which is 7.3 meters deeper than the main\r\nfield water level. The resulting gross pay interval is 11.6 meters of which\r\n100% is net pay using CPI field cut off values of 65% water saturation, 40%\r\nv-clay or 12% porosity. Average CPI measured porosity in the pay section is\r\n22.1% and water saturation is 37%.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe Statfjord Group was penetrated at\r\n2998 m and was found water wet.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eOne core was cut from 2611.5 to 2628.35 m\r\nwith 88.7% recovery. The core to log depth shift was estimated to be -2.3 m. FIT\r\nfluid samples were taken at 2624.5 m (failed test), 2617.","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"406","properties":{"OBJECTID":406,"wlbNpdidWellbore":411,"wlbName":"33/9-6","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 33/9-6 was drilled ca 3 km east of\r\nthe UK border on the 9-Delta prospect located on the regional Murchison structural\r\ntrend, which extends across the northern portion of block 33/9.\u003c/span\u003e\u003cspan\r\nlang=EN-GB\u003e \u003c/span\u003e\u003cspan lang=EN-GB\u003eThe well was the first wildcat in the Norwegian\r\nsector of the Murchison trend.\u003c/span\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003cspan lang=EN-GB\u003eThe\r\nprimary objective was the Brent Group sand, which is oil reservoir of the\r\nadjacent Murchison Field. The well was drilled near the crest of the structure\r\nwith a planned total depth of 3300 m, approximately 30 m into the Early\r\nJurassic Statfjord Formation.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 33/9-6 was spudded with the\r\nsemi-submersible installation Dyvi Alpha on 23 June 1976 and drilled to TD at 3354\r\nm in the Early Jurassic Statfjord Formation. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe Tertiary consisted primarily of\r\nclays, siltstones, and minor sands. The tuffaceous red claystone typical of the\r\nPaleocene was encountered slightly above the log pick at 1669.5 m. The sandy\r\nbasal portion of the Paleocene was not well developed in 33/9-6. Oil and gas\r\nshows have occurred in this zone in both Statfjord and Murchison Field wells;\r\nhowever, no-shows were observed in 33/9-6. The objective Brent Group was encountered\r\nat 2995 m, 7.5 m low to prognosis. The sand was described as clear to white,\r\nfine grained and very micaceous. Porosity was poor to fair; and poor to fair\r\noil shows and scattered thin zones of bleeding oil were described down to 3023 m.\r\nNo shows occurred below 3023 m. Schlumberger Coriband Log analysis and core\r\ndata indicated 24.5 meters of gross pay and 13.5 meters of net pay, and an\r\noil/water contact of 3019.5 m. Based on this reserves for the horst block alone\r\nwere estimated at only ca 900000 Sm3 oil","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"407","properties":{"OBJECTID":407,"wlbNpdidWellbore":412,"wlbName":"33/9-7","wlbHistory":"\u003cht\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 33/9-7, was drilled on the 33/9-Alpha\r\nprospect, 2.5 km east of the Statfjord Field in the Tampen Spur area in the\r\nnorthern North Sea. The primary objective was to test a part of the\r\nBrent-Statfjord trend separated from the Statfjord Field to the west by a\r\nstructural saddle. The primary target was the Brent Group sandstones.\r\nSandstones within the Statfjord Group was a secondary target.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 33/9-7 was spudded with the semi-submersible\r\ninstallation Dyvi Alpha on 11 September 1976 and drilled to TD at 3127 m in the\r\nStatfjord Group. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eGood oil and gas shows seen in a 50-meter\r\nthick sequence of interbedded sands and claystones in the lower portion of the\r\nPaleocene from 1770-1820 m. The sands although not apparently continuous, were\r\noil stained and had good gas shows throughout the interval. Log evaluation was\r\nnot practical due to washing out resulting in excessive hole sizes. The Brent\r\nGroup sandstones came in sandstones at 2461 m. There was 160 m net sand with\r\naverage 27% porosity. The sands were oil-filled down to a section of\r\nclaystones, coals and minor sands at 2520 m. An OWC was inferred at 2533 m. No\r\nshows were observed in the Statfjord sands, but the logs indicated scattered\r\nresidual oil.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eA total of 103.33 m core (86% recovery)\r\nwas cut in nine cores in the interval 2465 to 2597 m in the Brent Group. No fluid\r\nsamples were taken on wire line.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was permanently abandoned on 7\r\nNovember 1976 as an oil discovery.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eTesting\u003c/span\u003e\u003c/b\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThree drill stem tests were car","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"408","properties":{"OBJECTID":408,"wlbNpdidWellbore":413,"wlbName":"33/9-8","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 33/9-8, was drilled on a prospect\r\nnorth of the main Statfjord Field in the Tampen Spur area in the northern North\r\nSea. The primary objective was to test sandstones in the Brent Group. Secondary\r\nobjective was the Statfjord Group\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 33/9-8 was spudded with the semi-submersible\r\ninstallation Deepsea Bergen on 11 November 1976 and drilled to TD at 3085 m in\r\nthe Statfjord Group. The original hole was abandoned at 2974 with stuck pipe. A\r\ntechnical sidetrack was kicked off from 2533 m. Top Brent Group is 6 m deeper\r\nin the sidetrack compared to in the original hole. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe sand and sand stringers generally\r\nassociated with the lower portion of the Paleocene in the area were not\r\ndeveloped in 33/9-8. An oil filled Intra-Draupne Formation sandstone was penetrated\r\nat 2670 m. This was the first encounter of Late Jurassic sandstone in the 037\r\nLicense area. The gross thickness of this sandstone is 45.8 m. Net sand was\r\nfound to be 34.8 m with 27% average porosity, based on log analysis. The whole\r\nsand was oil filled down to top Heather Formation at 2716 m. The Brent Group\r\nsandstones was encountered at 2740 m with oil down to the OWC at 2741.5 m.\r\nGross thickness of the Brent Group sandstones was 140.3 m. Net sand was found\r\nto be 124 m with 22% average porosity. The secondary objective Statfjord Group\r\nwas water wet without shows.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThree cores were cut in Late Jurassic\r\nViking Group the interval 2670 to 2724.8 m (54.8m). The core recoveries were\r\n2670 to 2671.27 m (7%), 2688.5 to 2706.26 m (97%), and 2706.8 to 2724.5 m (98%)\r\nfor cores one, two, and three, respectively. The cores were cut in the original\r\nhole. Add six meters to the core depths to match with the we","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"409","properties":{"OBJECTID":409,"wlbNpdidWellbore":414,"wlbName":"33/9-9","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 33/9-9 was drilled in the northern part\r\nof the Statfjord field, about 1.6 km southeast of 33/9-3 well on the Tampen\r\nSpur in the northern North Sea. The objectives were to provide structural and\r\nstratigraphic control on the Brent reservoirs, and to provide stratigraphic\r\ncontrol and to establish an oil/water contact for the Statfjord reservoir.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 33/9-9 was spudded with\r\nthe semi-submersible installation Borgny Dolphin on 27 July 1977 and drilled to\r\nTD at 3100 m in Late Triassic sediments in the Statfjord Formation. The well\r\nwas drilled with seawater down to 486 m and with a seawater/lignosulphonate mud\r\nsystem from 486 m to 1993 m. At 1993 m, TD in the 17 1/2" section, the\r\nhole was displaced to a freshwater/Lignosulphonate mud system. At the same\r\npoint diesel was added to free the 13 3/8" casing which had become\r\ndifferentially stuck. After that the mud contained initially 5% diesel\r\ndecreasing to traces of diesel at to 2489 m. From 2489 m to final TD the\r\nfreshwater/Lignosulphonate mud system was without measurable diesel.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo hydrocarbon shows were reported above\r\nthe Brent Group. The Brent Group was found at 2413 m, 77.5 m deeper than\r\nprognosed 44.0 m thinner than anticipated in comparison to 33/9-3. Good oil\r\nshows were encountered at the top of the Brent Formation and continued\r\nthroughout the reservoir down to top Dunlin Group at 2504 m. The entire Brent Group\r\nwas oil-filled and it was above the field oil/water contact of 2609.1 m (2584.1\r\nMSL). Log calculations showed that of the 87.0 m of gross oil section 84.6 m was\r\nnet sand with 27.5% average porosity and 13.1% average water saturation. The\r\nDunlin Group came in at 2504 m and log interpretation indicated a 23.2 m gross oil\r\nbea","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"410","properties":{"OBJECTID":410,"wlbNpdidWellbore":415,"wlbName":"33/9-10","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\u003cp\u003eWildcat well 33/9-10 is located on the Tampen Spur North of the Murchinson Field.\r\nThe Middle Jurassic Brent sand was the primary objective with the Early Jurassic\r\nStatfjord sand as a secondary objective. Planned TD was 3695 m, interpreted to be 30 m\r\ninto the Statfjord Formation. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\u003cp\u003eWildcat well 33/9-10 was spudded with the semi-submersible installation Fernstar\r\non 7 April 1978 and drilled to TD at 3715 m in the Early Jurassic Statfjord Formation.\r\nThe well was drilled with Spud down to 516 m, with seawater/FCL polymer mud\r\nfrom 516 to 1820 m, with lignosulphonate/fresh water from1820 to 3491 m, and with\r\nQbroxin/CC-16/fresh water from 3491 m to TD. Spots of diesel and protectomagic\r\n(water or diesel-dispersed asphalt) was added to the mud, beginning at 1820 m.\r\nFrom 1820 m, oil in the mud was reported at contents varying between 3% and 20%. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe electric log pick of the top of the Early Cretaceous Cromer Knoll Group was\r\ntaken at 3113 m, giving an Early Cretaceous thickness of 146.8 m. The Early Cretaceous\r\nconsisted of 20.3 m of Barremian limestone at the base with red marl interbedded with\r\nthe overlying claystone section. \u003c/p\u003e\r\n\r\n\u003cp\u003eTop Late Jurassic Viking Group was picked at 3259.8 m, 15.7 m high to prognosis.\r\nThe thickness was 88.2 m of which the upper 69.2 m was the Draupne Formation and the\r\nlower 19 m was the Heather Formation. The lithology of the Viking Group was grey to\r\ndark grey, silty claystone. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe primary objective Brent Group was penetrated at 3348 m, 37.5 m high to prognosis.\r\nThe sandstone was argillaceous, medium grained, and had fair to poor porosity.\r\nOf the expected 140 m of Brent Group, only 67.5 m was found. Of this 37 m was net sand.\r\nThe Brent Group was water bearing. No shows were seen in the ditch samples. One core\r\nwas cut from 3358 m to 3376 m. Very poor shows were observed in the core, but electric\r\nlogs and Schlumberger Coriband analysis indicated the Brent Formation to be water wet.","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"411","properties":{"OBJECTID":411,"wlbNpdidWellbore":416,"wlbName":"33/9-11","wlbHistory":"\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 33/9-11 was drilled to test\r\nthe 33/9-Epsilon prospect 6 kilometres north of the 33/9-Beta oil discovery and\r\n10 kilometres northeast of the Murchison Field (UK). The Epsilon structure is a\r\nnorthwest tilted fault block and is expressed as a topographic high at the\r\nKimmerian Unconformity surface. The primary objective was to test the hydrocarbon\r\npotential in the Middle Jurassic Brent Sand. The Early Jurassic Statfjord Sand was\r\nsecondary objective.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eExploration well 33/9-11 was spudded with\r\nthe semi-submersible installation Fernstar on 17 June 1978. The spud location\r\nturned out to be in a 25 m diameter crater in the sea floor. Due to problems\r\nwith tilting of the temporary guide base two unsuccessful spuds were made\r\nbefore the third and successful spud was made with a modified guide base on 24\r\nJune 1978. Final position refers to this hole. The well was drilled with\r\nseawater and gel down to 820 m, with KCl polymer mud from 820 m to 1870 m, and\r\nwith a fresh water/lignosulfonate mud from 1870 m to TD. Diesel and\r\nProtectomagic was spotted below 820 m, and from this depth the mud is reported\r\nto contain between 4 and 12 % oil. The well was drilled to TD at 3528 m, 91 m\r\ninto the Early Jurassic Statfjord Formation.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eGrey clays and claystone dominated the\r\nTertiary except for the sands in the intervals, 989 to 1034m and 1205 to 1225m.\r\nIn the Paleocene Balder Formation typical tuffaceous grey and red claystone\r\nwere present and were also observed above and below the Balder. The Late\r\nCretaceous Shetland Group was comprised of grey and brown claystone and\r\nsiltstones with only minor sands and carbonates. The electric log pick of the\r\ntop of the Early Cretaceous Cromer Knoll Group was taken at 3037.8 m. The Early\r\nCr","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"412","properties":{"OBJECTID":412,"wlbNpdidWellbore":417,"wlbName":"33/12-1","wlbHistory":"\u003chtml\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 33/12-1 is the Statfjord Field\r\ndiscovery well. The well was drilled ca 400 m east of the UK boundary. The\r\nStatfjord Field is located in the Tampen Spur area of the North Sea. The\r\ndrilled structure is a west tilted fault block, forming part of a structural\r\ntrend extending across the U.K. - Norway boundary. The trapping mechanism for\r\nthe prospect was westerly dipping Jurassic beds bevelled at the Late Kimmerian\r\nregional unconformity. Cretaceous mudstones and marls provided the seal. The\r\nBrent Field is located on the southwestern U.K. portion of the same structural\r\ncomplex. The primary objective of the well was the Middle Jurassic sandstone\r\nsection known to be productive in the U.K. Brent Field. Secondary objectives\r\nwere Lias (Early Jurassic) and Triassic sands. The Paleocene section, which is\r\nstructurally high, was an additional objective although nearby wells did not\r\nhave reservoir rocks in this section.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 33/12-1 was spudded with the semi-submersible\r\ninstallation Waage Drill I on 1 December 1973 and drilled to TD at 3060 m in\r\nthe Triassic Lunde Formation. After drilling to 466 m, TD in 26" section,\r\n47 days were spent due to rough weather and problems with tensioners and riser.\r\nAfter this operations proceeded without significant technical problems, but the\r\nweather caused much interruptions and WOW.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThere were oil shows with relatively high\r\ngas readings in the interbedded siltstones and sandstones in the Paleocene\r\nsection and throughout the Maastrichtian. The Brent Group was encountered at\r\n2409 m and was oil filled down to top Dunlin Group at 2570 m. The oil-water\r\ncontact was not present in this well. From log analysis, 148 m of net sand with\r\nan overall average porosity of more than 28","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"413","properties":{"OBJECTID":413,"wlbNpdidWellbore":418,"wlbName":"33/12-2","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 33/12-2 was drilled in the Tampen\r\nSpur area as one of the first wells in the Statfjord Field area. Primary target\r\nof the well was the Early Jurassic Statfjord Group, which was known to be\r\nproductive in Brent Field located about 20 km to the southwest in the U.K.\r\noffshore. The Statfjord Formation was water wet in the 33/12-1 and 33/9-1\r\ntests. The 33/12-2 wildcat was located to encounter the Statfjord Formation\r\napproximately 200 m high to the 33/12-1 well. The Middle Jurassic Brent\r\nFormation was prognosed to be erosionally thin or absent. Triassic, Permian and\r\nDevonian reservoirs were secondary targets. Planned total depth was 4572 m\r\n(15000 ft.), believed to be sufficient to reach Devonian age rocks or\r\n"Petroleum Basement". The well was one of the three deep tests called\r\nfor by the License 037 work obligation. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well is type well for the Alke and\r\nLunde formations of the Hegre Group and the Raude and Eiriksson formations of\r\nthe Statfjord Group. It is reference well for the Nansen Formation.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 33/12-2 was spudded with the\r\nsemi-submersible installation Nordskald on 6 June 1974. \u00A0Drilling proceeded to 4354\r\nm in Early Triassic sediments of the Lomvi Formation. At this depth the drill\r\nstring twisted off leaving a fish with top at 4157 m. Attempts to remove the\r\nfish were unsuccessful so 4354 m became TD of the well. No wire line logs were\r\nrun below 4145 m. The well was drilled with water-based mud. Below 2716 m the\r\nmud contained from 2% to 8% oil.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAs predicted, the Middle Jurassic Brent Group\r\nwas thin (17.5 m) and oil bearing (12 m net). Test data and log correlation\r\nindicated that the upper reservoir in the 33/12-2 well is a sectio","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"414","properties":{"OBJECTID":414,"wlbNpdidWellbore":420,"wlbName":"34/2-1","wlbHistory":"\r\n\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eExploration well 34/2-1 is located a\r\nnorthwestern part of the Tampen Spur area. It was intended to be the first well\r\nto test the reflections below the Base Cretaceous (Kimmeridgian) Unconformity\r\non a seismically defined, northerly trending west-northwest dipping fault\r\nblock. The well was located near the apex of the structure at the Base\r\nCretaceous level, but down-dip with respect to deeper stratigraphy. Primary\r\ntargets were the Middle Jurassic Brent Formation and the Early Jurassic/Triassic\r\nStatfjord Formation. Secondary targets were possible Early Tertiary and Late\r\nJurassic sandstones. Planned TD was 4300 m Sub Sea. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 34/2-1 was spudded with the\r\nsemi-submersible installation Byford Dolphin on 29 December 1979. Due to\r\nproblems with the guide line and instability of the temporary guide base three\r\nunsuccessful spuds were made before a successful spud was made on 23 January\r\n1980. The well was drilled to TD at 807 meters in the Tertiary. Being unable to\r\nlatch the BOP onto the 20-inch wellhead, 34/2-1 was permanently abandoned on 23\r\nFebruary 1980 as a junked well. A total of 68 days was spent on the well.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was performed.\u003c/p\u003e\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"415","properties":{"OBJECTID":415,"wlbNpdidWellbore":421,"wlbName":"34/2-3","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eBlock 34/2 lies at the very northern end\r\nof the Tampen Spur and is located at the convergence of pre-Cretaceous Highs\r\ntrending through Block 34/4 from Brent/Statfjord, from Dunlin/Murchison, from\r\nthe 34/10 area and from a similar high trend through Block 34/5 from Block\r\n34/8. The block was awarded in License 56 in 1979. The first well in the\r\nLicense (34/2-1) was spudded on 29 December 1979 and junked and abandoned on 19\r\nFebruary 1980 at 850 m, due to technical problems. As the first well did not\r\nsatisfy License commitments, it was agreed among the partners that Well 34/2-2\r\nwould be drilled at the same location with the same objectives. This well was\r\ndrilled to 4074 m and plugged and abandoned after having found poor reservoir\r\nconditions and no hydrocarbon accumulations. Well 34/2-3 was drilled 3.25 km to\r\nthe northwest of Well 34/2-2 on the northern end of the Tampen Spur. The main\r\nobjective was to test the sedimentary section below the Base Cretaceous\r\nUnconformity in a seismically defined northeasterly trending horst block.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was spudded with the\r\nsemi-submersible installation SEDCO 703 on 15 May 1981. Due to boulder beds at\r\nthe location the first 36-inch interval was unsuccessful. The well was\r\nrespudded on 17 May 1981 and drilled to TD at 3742 m in the Late Triassic Lunde\r\nFormation. The well was drilled with spud mud down to 815 m, with\r\ngypsum/lignosulphonate from 815 m to 3340 m, and with\r\ngel/chemtrol/lignosulphonate from 3340 m to TD. \u003c/p\u003e\r\n\r\n\u003cp\u003eWhile drilling between 820 m and 890 m\r\nshallow gas was encountered, giving readings of up to 7% total gas. However,\r\nthis caused no drilling problems. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe well penetrated Tertiary and\r\nCretaceous sediments down to the Barremian Rødby Formation, which was found\r\nunconformably overlying Late Triassic Lunde Formation. No significant reservoir\r\nzones were encountered above Top Trias. The Lunde Formation consisted of\r\ninterbedded shales, siltstones, sandsto","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"416","properties":{"OBJECTID":416,"wlbNpdidWellbore":422,"wlbName":"34/4-1","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 34/4-1 was drilled on the\r\nrotated fault block systems on the Tampen Spur area of the Northern North Sea. The\r\nobjective of the well was to test the stratigraphic sequence below the Base\r\nCretaceous Unconformity. The primary target was the Intra Triassic\r\n"Carnian Sandstone", which was known from two wells in block 33/12\r\nwhere it constitutes more than 100 m silty, argillaceous, partly calcareous\r\ncemented sandstone. The secondary targets were possible reworked Late Jurassic\r\nsandstones immediately below the Unconformity, and by possible sands associated\r\nwith stratigraphically undefined seismic reflectors between Base Cretaceous and\r\nCarnian level.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 34/4-1 was spudded with the\r\nsemi-submersible installation Byford Dolphin on 11 July 1979. The well was\r\nfirst drilled to 2961 m. When pulling out of hole to change bit it got stuck.\r\nThe bit could not be worked free and the drill string was eventually backed off\r\nand left in the hole. A sidetrack was made from 2484 m and drilled to final TD\r\nat 2916 m in the Triassic Teist Formation. The well was drilled with seawater\r\nand viscosity slugs down to 844 m, with Drispac/Unical/gypsum mud from 844 m to\r\n1988 m, and with Drispac/Unical mud from 1988 m to TD, including sidetrack. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe well penetrated Tertiary, Cretaceous\r\nand Triassic rocks with a hiatus ranging from Late Triassic to Early Cretaceous\u003c/p\u003e\r\n\r\n\u003cp\u003eSecondary target for the well was\r\nreworked Late Jurassic sediments immediately below Base Cretaceous. Such\r\ndeposits were not established. The Triassic sandstones (Lunde Formation) were\r\nencountered at 2508 m and contained oil over a column of more than 100 m. No\r\ndefinite OWC was seen, but it could be estimated to be at 2618 m. Numerous\r\nshows on sandstone stringers were observed in the Cretaceous from ca 2025 m\r\n(top Kyrre Formation) and down to top of the Triassic reservoir. No shows were\r\nobserved below 2622 m.\u003c/p\u003e\r\n\r\n\u003cp\u003eEleven cores were cut in","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"417","properties":{"OBJECTID":417,"wlbNpdidWellbore":423,"wlbName":"34/4-3","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eExploration well 34/4-3 is located in the\r\nMarulk Basin north-northwest of the Snorre Field. It was drilled as the third\r\nwell on the Gamma Structure and had a wedge structure between the Base\r\nCretaceous Unconformity and the Late Jurassic Unconformity as primary target.\r\nSecondary objectives were to penetrate the Brent Equivalent and the Statfjord\r\nformation. The well is located on the downthrown side of a NE-SW trending major\r\nfault, and the sealing nature of this fault was critical for a closure of the\r\nreservoir.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 34/4-3 was spudded with the\r\nsemi-submersible installation Dyvi Alpha on 16 October 1981 after waiting on\r\nlocation for two weeks due to bad weather. The 26" section was drilled\r\nwith a 21 1/4" BOP installed but after pulling the riser and the BOP a\r\n26" bit was run in the hole since the underreamer did not perform.\r\nDrilling of the 17 1/2" section was delayed by nearly two weeks due to the\r\n18 3/4" BOP not meeting requirements. During drilling of the 12 1/4"\r\nsection electrical problems on the draw works as well as mud pump breakdowns\r\nand high pressures was experienced. Drilling the 8 1/2" section included 4\r\ncore runs, killing a water/methane kick at 3555 m, changing leaking seals on riser\r\nand two intermediate log runs. TD was reached at 4460 m in Late Triassic\r\nsediments. The well was drilled with seawater/bentonite/gel down to 516 m, with\r\ngel/gypsum from 512 m to 1019 m, with gypsum/polymer from 1019 m to 2209 m, and\r\nwith lignosulfonate mud from 2209 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eA methane gas/water kick occurred at 3550\r\nm when the first Late Jurassic sandstone stringer was entered, giving 21 %\r\ntotal gas. A more continuous Late Jurassic sand was drilled into at 3565 m. Two\r\ncores (18 m) were cut in this 27 m thick sandstone sequence. The cores consist\r\nof shallow marine laminated shale/silt/sandstone. The sandstone is grey, very\r\nfine to fine grained with average porosity 10%","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"418","properties":{"OBJECTID":418,"wlbNpdidWellbore":424,"wlbName":"34/10-1","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 34/10-1 was the first well to be\r\ndrilled on the "Delta structure" (Gullfaks fault block) in the Northern\r\nNorth Sea. The primary objective of the well was to penetrate sandstones of Early\r\nto Middle Jurassic age and to evaluate their possible content of hydrocarbons.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 34/10-1 was spudded with the\r\nsemi-submersible installation Ross Rig on 20 June 1978 and drilled to TD at 2460\r\nm in the Late Triassic Lunde Formation. The 30" casing was set after\r\nconsiderable difficulty in getting through a section of boulders. A severe well\r\nkick was taken after a flow check at 1780 m, ca 3 m above top reservoir. Ca 440\r\nbarrels of mud were gained in the pit. Otherwise the operations proceeded\r\nwithout significant problems. No directional survey was run below1737 m. The\r\nwell was drilled with seawater and gel slugs down to 214 m, with fresh water\r\nand gel from 214 m to 504 m, with seawater/gel/lignosulphonate from 504 m to\r\n1970 m and with Seawater/gel/spersene/XP20 from 1970 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eFirst oil show, pale yellow fluorescence\r\nin limestone and siltstone, was recorded at 1370 m in the Hordaland Group.\r\nSimilar shows continued down to top Brent Group level interrupted only by a\r\nshort interval of no shows from 1579 to 1600 m. At 1555 in the Balder Formation\r\ntrace oil in the mud was observed. Top reservoir, Tarbert Formation, was\r\nencountered at 1783 m directly underlying the Late Cretaceous Shetland Group. Oil\r\nwas proven in sandstones all through the Middle Jurassic Brent Group down to\r\ntop Drake Formation in the Dunlin Group. The oil/water contact was not observed\r\nin the well. Below reservoir level shows decreased and died out completely\r\nbelow 2325 m. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eA","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"419","properties":{"OBJECTID":419,"wlbNpdidWellbore":425,"wlbName":"34/10-2","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 34/10-2 was drilled on the "Alpha\r\nclosure" in the northern North Sea, ca 8 km south of the 34/10-1 Gullfaks\r\ndiscovery drilled three months earlier on the "Delta structure". The\r\nprimary objective of 34/10-2 well was to test sandstones of the Middle Jurassic\r\nseries. The secondary objectives were sandstones of the Paleocene and Early\r\nJurassic series.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 34/10-2 was spudded with the\r\nsemi-submersible installation Ross Rig on 9 September 1978 and drilled to TD at\r\n3729 m in the Late Triassic Lunde Formation. No significant problem was\r\nencountered during drilling, but close to15 days were spent as WOW due to\r\nsevere weather conditions, and final logging at TD suffered from the weather.\r\nThe well was drilled with spud mud down to 517 m, with gel/lignosulphonate mud\r\nfrom 517 m to 1723 m, and with gel/lignosulphonate/"ADF Chrome\r\nLignite" mud from 1723 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 34/10-2 proved the presence of gas\r\nin sandstones of Middle Jurassic Brent Group and oil in sandstones of the Early\r\nJurassic Statfjord Formation. The Brent Group was hydrocarbon bearing all\r\nthrough from top at 2944 m down to top Dunlin Group (Drake Formation) at 3124\r\nm. A total of 109 m was net pay sandstone with average porosity 20.8% and\r\naverage water saturation 13.8%. The gas/oil/water contact was not seen. The Statfjord\r\nFormation was oil bearing from 3325 m down to ca 3390 m based on the well logs.\r\nIt contained 31.75 m of net pay oil bearing sandstone with average porosity\r\n15.9% and average water saturation 21.6%. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eShows started at 1640 m. These were\r\ndescribed typically as gold yellow fluorescence and fast streaming milky cut on\r\nclaystones with trace sands","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"420","properties":{"OBJECTID":420,"wlbNpdidWellbore":426,"wlbName":"34/10-3","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 34/10-3 was the second well drilled\r\nin the Delta closure in block 34/10\u003c/span\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003cspan\r\nlang=EN-US\u003ein the Northern North Sea\u003c/span\u003e\u003cspan lang=EN-GB\u003e.\u00A0 In the first\r\nwell, 34/10-1, hydrocarbons were tested and proven to be present throughout the\r\nBrent sand. \u003c/span\u003e\u003cspan lang=EN-US\u003eThe primary objective of the well \u003c/span\u003e\u003cspan\r\nlang=EN-GB\u003e34/10-3 \u003c/span\u003e\u003cspan lang=EN-US\u003ewas to test sandstones of Middle\r\nJurassic age. Secondary objectives were sandstones of Early Jurassic and Late\r\nTriassic age.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell was spudded with the\r\nsemi-submersible installation Norskald on 14 March 1979 and drilled to TD at 2802 m. When coring for core no 10\r\nthe core jammed at 2512.5 m and the core head matrix was left in the hole.\r\nFishing commenced for 3 and a half day until most of it was recovered.\r\nOtherwise the operation proceeded without any significant problem. The well was\r\ndrilled with seawater/gel down to 587 m and with Chrome Lignosulphonate mud\r\nfrom 587 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eOil shows (yellow fluorescence, cut and\r\n"dead oil stain" were recorded at 1410 - 1470 m at the base of the\r\nHordaland Group. Stronger shows were seen from 1814 m in the Shetland Group m\r\nand down to top Brent reservoir. Oil in the mud was observed at 1814 m. The Middle\r\nJurassic Brent Group was encountered at 1892 m, directly underlying a thin Albian-Aptian\r\nage Cromer Knoll section. The Brent Group was oil bearing down to the oil water\r\ncontact at 1972 m. Oil shows on cores continued down to 1997 m. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eEight cores were cut in succession from\r\n1904 m to 2025 m in the Brent Group, and one core was cut from 2467 m to 2478.8\r\nm in the Early Jurassic Amundsen Formation. No wire line fluid sample","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"421","properties":{"OBJECTID":421,"wlbNpdidWellbore":427,"wlbName":"34/10-4","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 34/10-4 was drilled in the Delta closure\r\nin the north-eastern part of block 34/10 in the northern North Sea. The Delta\r\nstructure consists of several separate fault blocks and 34/10-4 targeted one of\r\nthese. It was the third well drilled in the Delta closure. Two other separate\r\nfault blocks had previously proved oil bearing by well 34/10-1 located to the\r\nsouth, and well 34/10-3 located about 2 km north-west. The primary objective of\r\nwell 34/10-4 was to test sandstones of Middle Jurassic age. Secondary\r\nobjectives were sandstones of Early Jurassic age. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 34/10-4 was spudded with the\r\nsemi-submersible installation Ross Rig on 12 August 1979 and drilled to TD at 2600\r\nm in the Late Triassic Lunde Formation. No specific problems were encountered\r\nin the operations. The well was drilled with sea water and gel slugs down to\r\n641 m and with sea water, gel, lignite and lignosulphonate in various\r\nproportions from 641 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eA minor hydrocarbon-bearing interval was encountered\r\nin the Eocene from 1290 to 1307 m but the type of hydrocarbons could not be\r\ndetermined. The net Eocene "pay" was 8.25 m with average porosity of\r\n34.4% and average water saturation of 38.5%. The main target Brent Group sandstones\r\nwere encountered at 1816 m and were found oil bearing down to claystone at 1912\r\nm. It contained 81 m of net pay with an average porosity of 33.7% and an\r\naverage water saturation of 12.5%. The Statfjord Formation (2350 - 2481 m) was\r\nwater bearing with 61 m of net sand with an average porosity of 23.3%. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe first show was recorded on a well\r\nsite sample from 1280 m, just above the Eocene pay. It was described with\r\n"dead oil, dull fluorescence"","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"422","properties":{"OBJECTID":422,"wlbNpdidWellbore":428,"wlbName":"34/10-5","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 34/10-5 was drilled in the western\r\npart of the Delta Closure in Block 34/10 in the Northern North Sea. The primary\r\nobjective of well 34/10-5 was sandstones of Middle Jurassic age. Secondary\r\nobjectives were sandstones of Early Jurassic age.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 34/10-5 was spudded with\r\nthe semi-submersible installation Ross Rig on 18 October 1979 and drilled to TD\r\nat 2780 m in the Late Triassic Lunde Formation. Apart from lost circulation\r\nproblems in the 12 1/4" section the drilling itself went quite smoothly.\r\nHowever, almost 21 days were lost due to bad weather conditions. The well was\r\ndrilled with spud mud down to 518 m, with gel/lignosulphonate from 518 to 1775\r\nm, with gel/lignite/lignosulphonate from 1775 m to 2210 m, and with\r\ngel/lignosulphonate from 2210 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe Brent Group was encountered at 1896 m\r\nand was oil bearing down to the OWC at ca 1972 m. Test results indicated the\r\nsame fluid system as in the previous wells drilled on the structure.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eOil shows were recorded from 1250 m and\r\ndownwards more or less continuously on claystone, limestone and siltstone to\r\ntop Brent level. No shows were recorded below OWC.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eFour cores were recovered in the interval\r\nfrom 1917 to 1974.7 m. One RFT fluid sample from the Brent Group recovered ca\r\n0.5 l oil and 1 l of mud filtrate.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was permanently abandoned on 2\r\nJanuary 1980 as an oil appraisal well.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eTesting\u003c/span\u003e\u003c/b\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe Tarbert Formation was tested from\r\nperforations in the inte","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"423","properties":{"OBJECTID":423,"wlbNpdidWellbore":429,"wlbName":"34/10-6","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 34/10-6 was drilled on the northern\r\npart of the Delta structure in block 34/10 in the northern North Sea. It was\r\nthe fifth well drilled on the structure. All four foregoing wells had tested\r\noil in the Brent Group. The primary objective was to test Middle Jurassic Brent\r\nGroup. Secondary objectives were sandstones of Early Jurassic age.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 34/10-6 was spudded with\r\nthe semi-submersible installation Borgny Dolphin on 13 November 1979 and\r\ndrilled to TD at 2362 m. A total of 14.6% of the rig time was lost due to\r\nwaiting on weather. The other main causes of downtime was technical failure\r\nduring cementing of the 9 5/8" casing, followed by two squeeze jobs, repair\r\nof subsea equipment and lost circulation. The lost circulation was experienced on\r\nseveral occasions when drilling the 8 1/2" hole. The main reason for this\r\nwas that the 9 5/8" casing (and 13 3/8" casing) were set too high, causing\r\nlow formation integrity at the casing shoes. The well was drilled with spud mud\r\ndown to 308 m and with seawater/polymer from 308 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe Brent Group sandstones were\r\nencountered at 2075 m, about 100 m below the OWC established in the previous\r\nwells drilled on the Delta structure. The Brent Group was 215 m thick with 145\r\nm net of good reservoir sands (average porosity = 27.8 %). The Brent Group was\r\nwater bearing. Oil shows were seen from 1580 m to 1632 m in the Balder\r\nFormation, and from 1710 m to 1812 m in the Lista Formation and top Shetland\r\nGroup, otherwise no evidence of hydrocarbons was seen in the well.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo conventional cores were cut. The RFT\r\ntool was run for pressure points, but no wire line fluid samples were taken.\u003c/span\u003e\u003c/p\u003e\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"424","properties":{"OBJECTID":424,"wlbNpdidWellbore":430,"wlbName":"34/10-10","wlbHistory":"\r\n\r\n\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 34/10-10 was drilled on the Delta\r\nstructure situated in the Gullfaks Vest area in the north-eastern part of block\r\n34/10. The primary objective was to test sandstones of Middle Jurassic age. Secondary\r\nobjectives were sandstones of Early Jurassic and Late Triassic age. The well\r\nwas planned to be drilled into Triassic to a total depth of 2265 m.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eOn 10 July 1980 at 2330 hrs the semi-submersible\r\ninstallation Norskald was transferred from well 15/9-6 to well 34/10-10. After\r\nthe rig had been anchored up on the 34/10-10 location a strike broke out among\r\nthe drilling crew. Due to the strike the operation was one month delayed and\r\nthe well was not spudded until 15 August at 1930 hrs. The 36" hole was\r\ndrilled to 229 m with a 26" bit and a 36" hole opener without\r\ntemporary guide-base. Seawater was used with returns to the sea floor. The hole\r\nwas slugged with high viscosity mud prior to each connection. The riser was run\r\nand the diverter system installed. From 229 to 816 m in the Nordland Group\r\n(Miocene age) the well was drilled first as a 17 1/2" pilot hole and\r\nlogged, then with a 26" hole opener. When disconnecting the marine riser\r\non 21 August, the well started to flow. The rig was quickly moved off location\r\nand out of danger from the gas flow. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well flowed for approximately one and\r\na half hours the morning of the blowout and again for two and a half hours the\r\nsame evening. Periodic subsea observations over the next days, showed continued\r\nflow from the wellhead at a greatly reduced rate with only one brief surface\r\nindication of flow. Post-well analysis of the incident concluded that the gas\r\ncame from shallow sand at 4","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"425","properties":{"OBJECTID":425,"wlbNpdidWellbore":431,"wlbName":"34/10-13","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 34/10-13 was drilled on a horst\r\nblock in the eastern part of the Gullfaks Fault Block. The primary objective of\r\nthe well was to test the sandstone of Early Jurassic age (Statfjord formation).\r\nThe Secondary objective was Carnian sandstone.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 34/10-13 was spudded with\r\nthe semi-submersible installation Deepsea Saga on 24 August 1981 and drilled to\r\nTD at 3392 m, 76 m into the Carnian sandstone. At 1725 m, the well started to\r\nflow. The influx was circulated out with 1.69 s.g. mud. A total of 21.5 days\r\nwere lost due to a strike after the drilling of the 6" section had been\r\ninitiated. The well was drilled with spud mud down to 300 m, with seawater gel\r\nfrom 300 m to 893 m, and with gel/lignosulphonate mud from 893 m to TD. The RFT\r\ntool stuck at 2882 m during sampling. The tool was left in the hole and the\r\nwell was plugged back and tested. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eFirst oil shows, typically cut and/or fluorescence\r\non claystone and limestone cuttings, was recorded at 1350 m in the Hordaland\r\nGroup. The shows were described more or less continuous down to top Statfjord\r\nreservoir at 1924 m. When drilling mudstones, limestone and marl in the Lista\r\nFormation from 1656 to 1701 m there was oil in the mud. Oil was found from top Statfjord\r\nGroup at 1924 m and down to at least 2114 m in the Hegre Group where oil was\r\ntested on DST. No oil/water contact could be established in the Statfjord\r\nsandstone and pressure measurements in the Hegre Group were inconclusive. Shows\r\nwere recorded on sandstones down to 2450 m. \u00A0From petrophysical analyses the Statfjord\r\nGroup had 70 m net pay with 27% average porosity and 24% average water\r\nsaturation. The Hegre Group reservoir had 16.5 m net pay with average 27.8%\r\nporosity and 56% average w","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"426","properties":{"OBJECTID":426,"wlbNpdidWellbore":432,"wlbName":"35/3-1","wlbHistory":"\r\n\u003cp\u003eThe exploratory well, 35/3-1, was drilled\r\non block 35/3 in the northern Norwegian North Sea, approximately 65 km west of\r\nMåløy in western Norway. The location is east of the Norwegian Trench. The\r\ngeneral objective was to test the total stratigraphical sequence down to\r\npre-Jurassic strata. Within the sequence, sand development was predicted for\r\nthe Lower Cretaceous and the Early Jurassic, with a possibility for minor sands\r\nin Middle-Late Jurassic. The well should penetrate two seismic reflectors\r\nbelieved to represent top Early-pre Jurassic and basement, respectively.\r\nPlanned TD was at 5250 m.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 35/3-1 was spudded with the\r\nsemi-submersible installation Deepsea Saga on 19 July 1976. The well was terminated\r\nat 4475 m in the Dunlin Group (Middle Jurassic, Bajocian age). This was not the\r\nplanned TD, but due to high pressure the well was abandoned at this depth for\r\nsafety reasons. Because of this the two deep seismic reflectors were not tested\r\nin this well. The well was drilled with seawater and salt water gel/Milben mud\r\ndown to 982 m, with gypsum mud from 982 m to 2474 m, and with lignosulphonate\r\nmud from 2474 m to TD. \u003c/p\u003e\r\n\r\n\u003cp\u003eA number of Tertiary sands not normally\r\nencountered in this part of the North Sea, were penetrated in this well. In the\r\nEarly Jurassic, at 3805 m, a 215 m sequence of Agat Formation sandstone was\r\npenetrated. At 4145 m a 21 m sequence of Late Jurassic Intra Heather Formation\r\nsandstone was penetrated. Shows were encountered and described as follows: \u003c/p\u003e\r\n\r\n\u003cp\u003e"The first traces of hydrocarbons\r\nwere encountered in Early Cretaceous sand at 3865 m. The sand gave a poor show\r\nof dead oil with no direct fluorescence, but with slow, streaming, cream cut\r\nfluorescence. Similar shows were occasionally encountered over the interval\r\n3865 - 3975 m, partly with a fast, streaming, white cut fluorescence. At 3900 m\r\na relatively clean, fine to medium grained silica cemented sand showed light\r\nbrown stain, traces of pal","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"427","properties":{"OBJECTID":427,"wlbNpdidWellbore":433,"wlbName":"35/3-5","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 35/3-5 is located ca 13 km south of\r\nthe Agat Discovery. The primary target of the well was sandstones of Early\r\nCretaceous age, which had been found hydrocarbon bearing in the 35/3-2 and\r\n35/3-4 wells. The well was considered a wildcat due to the uncertain\r\ncorrelation between sand bodies in the area. The secondary objective was to\r\npenetrate sandstones of Middle - Early Jurassic age, which had been found\r\nhydrocarbon bearing in 35/3-2. \u003c/p\u003e\r\n\u003cp\u003eThe well is Reference well for the Agat Formation.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eExploration well 35/3-5 was spudded with\r\nthe semi-submersible installation West Venture on 22 December 1981 and drilled\r\nto TD at 4114 m in Basement rocks. The well was respudded two times due to\r\nboulders. Shallow gas caused problems with cementing and caused a leak outside of\r\nthe casing. The leak was repaired and further operations were performed without\r\nany specific problems. The well was drilled with seawater and hi-vis pills down\r\nto 420 m, with seawater/gel mud from 420 m to 1046 m, with gypsum/polymer mud\r\nfrom 1046 m to 2052 m, and with lignosulphonate mud from 2052 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe Agat Formation was encountered from\r\n3219 m to 3620 m. A thin Intra Heather sandstone was penetrated from 3865 m to\r\n3874 m. A minor show was noted at the top of the Agat Formation. Minor oil\r\nshows with associated formation gas peaks were recorded in sandstones at 3547 m\r\nand 3568 m. Minor shows were recorded in siltstones below 3685 m, but these\r\nwere not associated with gas peaks. Organic geochemical analyses confirmed\r\nmigrant hydrocarbons at 3223 m in the top of the Agat Formation. Source rocks\r\nwere immature down to about 3000 m. Oil window maturity is postulated below ca\r\n3900 m. Below ca 3300 m in the well total organic carbon was found in the range\r\n1.7 % to 3 % in picked mud stone samples. Shale in a thin interval at 3286 m to\r\n3295 m was evaluated as a good/rich potential as a source rock for gas and oil\r\nwhile claystone/siltston","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"428","properties":{"OBJECTID":428,"wlbNpdidWellbore":434,"wlbName":"35/8-2","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 35/8-2 is located in the\r\nSogn Graben north of the Fram Field. The main objectives were to test the\r\nMiddle Jurassic Brent Group as well as sands in the Early Jurassic Dunlin Group\r\nand Statfjord Formation on a structure located in the south western corner of\r\nthe block. No reservoirs were anticipated above the Late Kimmeridge\r\nUnconformity. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 35/8-2 was spudded with the\r\nsemi-submersible installation Sedco 704 on 30 August 1981 and drilled to TD at\r\n4336 m in the Early Jurassic Statfjord Formation Formation. During hole opening\r\nof the 36" section, the drill string parted and left the bit, opener and\r\ndrill collars in the hole. Fishing was unsuccessful. The well was re-spudded 11\r\nSeptember 1981 and the 17 1/2" pilot hole was drilled without problems.\r\nWhen opening to 36" washing and reaming was required. Few problems were\r\nencountered in the 26" section. While drilling the 17 1/2" hole one\r\nexperienced problems with tight hole at 830 to 883 m, 1610 -1720 m and 1915 -\r\n1940 m. Repairs of the BOP and other unrelated rig problems occurred for 13\r\ndays during the drilling of this section. Tight hole was also experienced in\r\nthe upper part of the 12 1/4" section and at 3100 m where pore pressure\r\nalso started increasing. Some problems were experienced when coring in the 8\r\n1/2" section. When running in hole with a new bit, the pipe became stuck\r\nat 3662 m. Twenty-one days were spent fishing before the hole was plugged back\r\ninto the 9 5/8" casing. The well was then sidetracked from 3482 m and the\r\n8 1/2" hole was drilled down to 3954 m. Some minor problems with tight\r\nhole and differential sticking occurred. A 6 1/8" hole was then drilled to\r\nTD at 4336 m. The well was drilled with seawater / pre-hydrated bentonite / gel\r\ndown to 2155 m and with seawater/bentonite/polymer/LF-5 mud from 2155 m to 3538\r\nm. From 3538 to TD the well was drilled with KCl/polymer mud, which w","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"429","properties":{"OBJECTID":429,"wlbNpdidWellbore":435,"wlbName":"36/1-1","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eBlock 36/1 was the most northern and\r\nshoreward block to be released by the Norwegian Government at the time well\r\n36/1-1 was drilled. The eastern boundary of the Block 36/1 is only 20 km from\r\nnear-shore islands and, at the closest point, approximately 26 km from the\r\nmainland. Wildcat well 36/1-1 is located northeast of the Agat Discovery, on\r\nthe eastern side of the Norwegian Trench. The main objective and target was\r\nMiddle Jurassic sands.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eExploratory Well 36/1-1 was spudded with\r\nthe semi-submersible installation Dyvi Alpha on 9 May 1975 and drilled to a\r\ntotal depth of 1596 meters in metamorphic gneiss. The well was drilled without\r\nany serious drilling problems. The mud used was a water based salt-water gel /Milben\r\nmud down to 515 m, adding lignosulphonate and CMC from 515 m to TD. \u003c/p\u003e\r\n\r\n\u003cp\u003eSands were encountered in the Early\r\nCretaceous interval from 1219 m to 1359 m. The target Middle Jurassic\r\nsandstones were encountered at 1463 m and extended down to top basement at 1568\r\nm. Coal seams were found between 1500 m to 1548 m. No hydrocarbon bearing\r\nformations were encountered in the well. Minor quantities of hydrocarbon were\r\nrecorded in the Cretaceous and Middle Jurassic sections but there were no major\r\nshows. It was assumed that the structure on which 36/1-1 was drilled is not an\r\neffective trap. Possibly the shales overlying the Middle Jurassic sandstones\r\nare too poorly compacted to constitute effective seals. Also, the major\r\neasterly bounding fault may bring sands of the Cretaceous against the Middle\r\nJurassic, thus destroying the effectiveness of the trap. One 6.1 m (80 %\r\nrecovery) conventional core was cut at TD. No fluid sampling was attempted on\r\nwire line.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned as dry\r\non 14 June 1975.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eTwo drill stem tests were conducted in\r\nthe Middle Jurassic: DST 1 from 1549.6 m to 1556 m and DST 2 from 1489.6 m to\r\n1496.6 m. No fluid reached the su","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"430","properties":{"OBJECTID":430,"wlbNpdidWellbore":436,"wlbName":"36/1-2","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThe exploratory well, 36/1-2, was drilled\r\non Block 36/1 in the northern Norwegian North Sea approximately 25 km west of\r\nMåløy in western Norway, east of the Norwegian Trench. The primary target of\r\nwell 36/1-2 was possible hydrocarbon bearing sandstones of the Middle and Late\r\nJurassic. The secondary target was possible hydrocarbon bearing Early\r\nCretaceous sandstones. The geological sequence on East Greenland shows\r\nfavourable sand developments in the Lower Cretaceous and similar depositional\r\nconfigurations might exist in the 041/042-license area. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well was spudded with the\r\nsemi-submersible installation Deepsea Saga on 26 August 1975 and drilled to TD\r\nat 3255 m in metamorphic gneiss basement. No significant problems were\r\nencountered during operations. The well was drilled with salt-water gel mud\r\ndown to 650 m, with gypsum mud from 650 m to 1406 m, and with lignosulphonate\r\nmud from 1406 m to TD. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe secondary target Early Cretaceous\r\nsandstone (Agat Formation) was encountered from 2815 m to 2865 m. The primary\r\ntarget Jurassic sandstones were found to be Intra Heather Sandstone, from 3146\r\nm to top of the basement at 3233 m. No hydrocarbons were found on logs, but\r\nshows, often characterized as "tary dead oil", were encountered from\r\n2330 m in the Late Cretaceous Tryggvason Formation down to 3192 m in the Late\r\nJurassic Intra Heather sandstone. The strongest shows were recorded in silty\r\nsandstone of the Agat Formation from 2815 m to 2825 m, described in well reports\r\nas " light brown stain, pale yellow fluorescence and weak, white,\r\nstreaming cut, accompanied by traces of oil in mud."\u003c/p\u003e\r\n\r\n\u003cp\u003eOne conventional core was cut over the\r\ninterval 2987.4 m to 3005.8 m with 100% recovery. The core was taken on sand\r\nindication in middle Jurassic, but the recovered core consisted of shale with a\r\nthin stringer of tight siltstone. Five FMT samples were attempted in the\r\ninterval 3154.5 m to 31","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"431","properties":{"OBJECTID":431,"wlbNpdidWellbore":437,"wlbName":"6507/12-2","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThe purpose of drilling the second\r\nexploration well offshore Mid-Norway was to test the whole stratigraphic\r\nsequence between the seabed and 5000 m or basement whichever came first, as\r\nspecified in the licence agreement,\u003c/p\u003e\r\n\r\n\u003cp\u003eVertical closures near base Jurassic, top\r\nLower Triassic, and a possible Permian marker represented the primary targets.\r\nAny horizon below the mapped Near Base Jurassic reflector would, according to\r\nSaga's interpretation, also be closed and thus represent a possible trap. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 6507/12-2 was spudded with the\r\nsemi-submersible installation Byford Dolphin on 9 June 1981 and drilled to TD\r\nat 5008 m in the Triassic Red Beds. When pulling out of hole after drilling the\r\n17 1/2" to 1005 m a shallow gas kick was taken. The drill string got stuck\r\nm in the 8 1/2 " section at 3620 and could not be freed. The well had to\r\nbe plugged back and sidetracked from 3347 m. The well was drilled with sea\r\nwater and gel down to 354 m, with gel/gypsum mud from 354 m to 1005 m, with\r\nPAC/polymer/gypsum mud from 1005 m to 2522 m, and with salt saturated lignite\r\nmud from 2522 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well turned out to be dry except for\r\ntraces of hydrocarbons in a few minor sand-streaks in the Upper Triassic Red\r\nBed sequence. Correlation to the well 6507/12-1 demonstrated generally that all\r\nthe layers were thinning towards the hinge of the platform. In the Triassic,\r\ntwo significant salt units were encountered, with a total thickness of 800 m,\r\nseparated by more than 500 m claystones/shales. Two cores were cut. The first\r\nwas cut from 1929.3 m to 1947.3 m, but nothing was recovered on the rig. The\r\nsecond was cut from 4975 m to 4985 m with 92% recovered. The FIT-samples were\r\nattempted through the liner and the 9 5/8" casing at two levels (3010 m\r\nand 3002 m), but build up pressure was not achieved. The fluid sample\r\nrecoveries were respectively 560cc and 550cc, both composed predominantly of\r\nmud filtrate.\u003c/","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"432","properties":{"OBJECTID":432,"wlbNpdidWellbore":438,"wlbName":"15/12-4","wlbHistory":"\r\n\r\n\u003cp\u003eWildcat well 15/12-4 is located on the\r\nMaureen Terrace in the South Viking Graben in the North Sea. The primary\r\nobjectives were the Palaeocene Heimdal Formation and sandstones of Jurassic and\r\nTriassic age. Secondary objectives were the Frigg Formation and fractured limestone\r\nin the Cretaceous. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 15/12-4 was spudded with the\r\nsemi-submersible installation Deepsea Bergen on 13 September 1984 and drilled\r\nto TD at 3157 m, 17 m into the Triassic Group. Operations were completed\r\nwithin the time schedule and with very few problems. The well was drilled with\r\nseawater and gel down to 505 m, with gypsum polymer from 505 m to 2680 m, and\r\nwith lignosulphonate from 2680 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eNo Heimdal or Frigg sands were encountered\r\nin the well. From logs and cores hydrocarbons were seen in the uppermost part\r\nof the Cretaceous chalk in the interval 2490 ? 2515 m. Core analysis and log\r\nanalysis indicated very poor reservoir properties in this chalk. The water\r\nsaturation was high (60 - 80 %) and the permeability was extremely low (0.01 -\r\n0.5 mD). A 1.5 meter oil column was seen in the Jurassic sandstone, from 2911.5\r\nto 2913 m with a transition zone down to 2915.5. Apart from these two intervals\r\nthere were no shows or other hydrocarbon indications in the well.\u003c/p\u003e\r\n\r\n\u003cp\u003eFour cores were cut, one in the Palaeocene,\r\ntwo in the Late Cretaceous and one in the Late Jurassic sequence. One FMT run\r\nwas made in the Cretaceous. Here, no pressure points out of 19 attempts were\r\nsuccessful due to seal failure and very low permeability in the formation. One\r\nattempt to get sample at 2439.5 m failed due to tight formation. In the\r\nJurassic a segregated FMT sample was taken at 2912 m (5.8 l oil with a density\r\nof 0.847 g/cm3 in the 2 3/4 gallon chamber) and a second segregated sample at\r\n2913.5 m (0.5 l oil and 9 l water/mud filtrate in the 2 3/4 gallon chamber).\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 31\r\nOctober 1984 as an oil discovery.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"433","properties":{"OBJECTID":433,"wlbNpdidWellbore":439,"wlbName":"31/2-15","wlbHistory":"\r\n\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 31/2-15 was drilled in the northern\r\npart of the Troll West oil and gas province to evaluate reservoir quality and\r\ndevelopment in the northern part of the Troll West accumulation, and to\r\nestablish fluid contacts in an undrilled fault compartment. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eAppraisal well 31/2-15 was spudded with\r\nthe semi-submersible installation Borgny Dolphin on 10 September 1984 and\r\ndrilled to TD at 1677 m in the Middle Jurassic Fensfjord Formation. No major\r\nproblems were encountered in the operations. The well was drilled with seawater\r\nand hi-vis pills down to 810 m, with KCl/polymer mud from 810 m to 1460 m, and\r\nwith chalk mud (calcium chloride/calcium carbonate) from 1460 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eTop reservoir was encountered at 1482 m\r\nas prognosed, but the age of the upper part was found to be of\u00A0 Paleocene and\r\nnot Late Jurassic age. The expected Sognefjord Formation came in at 1515 m. The\r\nwell thus correlate with the situation in well 31/2-18 and 31/2-18 A. Both the\r\nPaleocene sand and the Sognefjord Formation sand were gas filled, and the gas\r\ncontinued down to a low permeable micaceous gas/oil transition zone at 1561 m\r\nto 1567 m. Testing and sampling proved no mobile oil down to at least 1567 m,\r\nand the free oil level was concluded to be very close to the Field-GOC at 1572\r\nm (1547 m SS). The OWC was unambiguously placed at 1583 m, in a highly\r\npermeable sand. No shows were recorded above 1482 m or below 1583 m. From\r\npetrophysical analysis there were indications of gas saturation in poor quality\r\nformation within a 10 m interval below top Fensfjord. However an RFT sample\r\nfrom his interval contained no oil, only gas and brine.\u003c/p\u003e\r\n\r\n\u003cp\u003eTwelve cores were cut from 1486 m to 1595\r\nm from the lower Paleocene, the Late Jurassic and Sognefjord Formation, and\r\ninto the Heather Formation. A total of 4 RFT samples were taken. Of these 2\r\ninitial failed because of tight formation and seal failure while brine and gas\r\nwere recovered from the sam","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"434","properties":{"OBJECTID":434,"wlbNpdidWellbore":441,"wlbName":"25/10-1","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 25/10-1 is located in the western\r\npart of the Balder Field in the North Sea. It was drilled on the crest of an\r\nEocene structure up dip from the 25/11-1 Balder Discovery well, which had thin,\r\noil-bearing Lower Eocene sands underlain by wet Paleocene sands. The purpose was\r\nto test this structure, and it was anticipated that 25/10-1 would find the\r\nPaleocene sands structurally higher and oil-bearing.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eAppraisal well 25/10-1 was spudded with\r\nthe vessel Glomar Grand Isle on 4 August 1969. The pipe got stuck at 1572 m.\r\nFishing was unsuccessful and a technical sidetrack was made. The well was\r\ndrilled to 1747 m (TD) into Paleocene shale belonging to the Sele\r\nFormation, where it was plugged and suspended due to severe winter autumn\r\nstorms. A later re-entry would complete the well objectives. Initial drilling\r\nfrom the set floor to 997 m was with sea water and gel. From 997 m to TD, the\r\nmud system consisted of seawater/spersene XP-20, Splinex mud.\u003c/p\u003e\r\n\r\n\u003cp\u003eDown to top Oligocene at 1247 m the\r\nsediments were composed of soft clays and unconsolidated sands and silts with\r\nno indication of hydrocarbons. The lower part of the well section (Early\r\nEocene, Balder Formation) was predominantly grey shale with very thin sands developed\r\nbelow a volcanic ash zone near the base. These sands had good oil shows and\r\ntested 24.8 - 25.1 deg API gravity oil on wire line formation tests in the\r\nre-entry well 25/10-1 R, but were too thin to be considered commercial. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe section from 1664.8 to TD in this\r\nwell was cored all through in eight cores, with near 100% total recovery. A\r\nfurther five cores in partially overlapping lithology, were cut in the re-entry\r\nwell 25/10-1 R. No wire line tests were performed in this well, but a number of\r\nwire line FITs, including fluid sampling, were taken in the re-entry well.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was suspended on 16 October 1969.\r\nIt is classified as a well with shows.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"435","properties":{"OBJECTID":435,"wlbNpdidWellbore":442,"wlbName":"34/7-3","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 34/7-3 was drilled on the Snorre E\r\nstructure in the northern part of block 34/7. The purpose was to further\r\nappraise the reservoir potential of the Statfjord Formation and upper Lunde\r\nFormation in the E-structure extension of the Snorre Discovery and to test the oil/water\r\ncontact found in wells 34/4-4 and 34/7-1.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 34/7-3 was spudded with the\r\nsemi-submersible installation Vildcat Explorer on 14 September 1984 and drilled\r\nto TD at 3414 m in the Late Triassic Lunde Formation. Drilling proceeded\r\nwithout significant problems. The well was drilled with spud mud down to 454 m,\r\nwith gel mud from 454 m to 1165 m, with KCl/Polymer mud from 1165 m to 2769 m,\r\nand with ligno/lignosulphonate mud from 2769 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well consisted mainly of claystones\r\nin the Tertiary and Cretaceous sections, with the exception of sand development\r\nin the Utsira Formation (Miocene), and an Early Oligocene sand development\r\n(1288 - 1323 m). The rest of the well, the Jurassic and Triassic sections, was\r\nmainly composed of alternating claystone/sandstone sequences. Top Statfjord was\r\nencountered at 2414 m.The Statfjord and Lunde Formations were oil filled down\r\nto a common OWC at 2610 m based on pressure gradients. Strong shows on cores continued\r\ndown to 2622 m, below this depth the shows became weak and spotted. Apart from\r\nthis oil shows, of variable quality, started in silty claystones at 2180 m in\r\nthe Late Cretaceous and continued down to 2755 m in the Lunde Formation.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eA total of 19 cores were taken in the\r\ninterval 2396 - 2643 m in the Jurassic (Dunlin- and Statfjord Formations) and\r\nthe Triassic sequence (Upper Lunde Formation). The core recovery was 91.5%.\r\nCore depth for core ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"436","properties":{"OBJECTID":436,"wlbNpdidWellbore":443,"wlbName":"24/6-1","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 24/6-1 was drilled on a\r\nstructure due west of the Heimdal discovery and approximately 1.5 km east of\r\nthe UK-Norwegian median line. The purpose of the well was to test superimposed\r\nprospects: Paleocene Heimdal sands, which exhibited a large structural high,\r\nand middle Jurassic Vestland Group sandstones on an intra-basin high faulted\r\npanel, dipping to the west and bounded to the north, east, and south by normal\r\nfaults.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 24/6-1 was spudded with the\r\nsemi-submersible installation Zapata Ugland on 9 February 1985 and drilled to\r\nTD at 4937 m in Early Jurassic sediments of the Statfjord Formation. Some\r\nproblems were experienced while cutting core no 2, due to weak formation below\r\nthe 9 5/8" shoe. The hole was plugged back to 4460 m, and a cement squeeze\r\nwas performed. This turned out to be not entirely successful, and the hole was\r\ndrilled to 4540 m where a 7" liner was set. Further drilling proceeded\r\nwithout problems. The well was drilled with bentonite/polymer/lignosulphonate\r\nabove 2820 m and with oil based mud from 2820 m to TD\u003c/p\u003e\r\n\r\n\u003cp\u003eThe thick Palaeocene sands were found\r\nwater bearing. The Turonian series (Tryggvason Formation) contained gas bearing\r\nlimestone reservoirs, which proved to be tight. Top of the Middle Jurassic\r\nHugin reservoir came in at 4478 m. It held a 100 m gas/condensate column with\r\nthe gas/water contact at 4578 m. Five conventional cores were cut over the\r\nHeimdal Formation and Hugin Formation sandstones. Five RFT fluid samples were\r\ntaken in the Hugin Formation at 4514.3 (gas + trace condensate), 4512 m (gas +\r\ntrace condensate), 4787.5 m (mud filtrate), 4706 m (contaminated formation\r\nwater), and at 4592 m (formation water). All samples showed unusual high oil\r\nfiltrate recovery due to unexpected deep invasion by the oil base mud.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 25\r\nAugust 1985 as a gas/condensate discovery. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eOne dri","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"437","properties":{"OBJECTID":437,"wlbNpdidWellbore":444,"wlbName":"6407/6-1","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 6407/6-1 was the third well to be\r\ndrilled on the TrØndelag Platform offshore Mid Norway. The primary objective of\r\nthe well was to investigate the reservoir potential of Middle Jurassic\r\nSandstones (Fangst Group). Secondary objectives of the well were the Early\r\nJurassic Sandstone Hl-2 (Tilje and Åre Formations), and sandstones in the\r\nTriassic.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 6407/6-1 was spudded with\r\nthe semi-submersible installation Zapata Ugland on 16 September 1984 and drilled\r\nto TD at 2895, 47 m into the Triassic Red Beds. In the 12 1/4" hole\r\nsection the hole suddenly packed off at 1591, probably due to overpressured\r\nEarly Eocene clays. The pipe was worked free and the mud weight increased.\r\nAfter that drilling proceeded without further difficulties. Logs were not run\r\nbelow 2869 m. The well was drilled with seawater/hi-vis slugs/gel down to 456\r\nm, with gypsum/lignosulphonate mud from 456 m to TD. The well proved a good\r\n"upper sandstone member" (Garn Formation), and a "lower\r\nsandstone member" (Ile Formation). Sandstone sequences interbedded with\r\nsiltstone, claystone, and coals were encountered also in the interval 2244 m to\r\n2457 m, the Tilje Formation. Isolated weak shows were recorded on core no 1 in\r\nthe lower part of the Garn Formation, otherwise no shows were observed in any\r\npart of the well. The RFT tool was run in the Middle Jurassic and four pressure\r\npoints were obtained in good to very good permability sandstone in the Garn\r\nFormation. The average gradient was 1.00 g/cm, indicating the formation was\r\nwater bearing. The electrical logs proved all reservoir sections in the well to\r\nbe water bearing.\u003c/p\u003e\r\n\r\n\u003cp\u003eFour cores were cut in the Middle\r\nJurassic Sandstone over the interval from 1870 - 1888.2 m. No fluid samples\r\nwere taken.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 26\r\nOctober 1984 as a dry well.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was performed.\u003c/p\u003e\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"438","properties":{"OBJECTID":438,"wlbNpdidWellbore":445,"wlbName":"6609/5-1","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 6609/5-1 was drilled on\r\nhorst structure in the western part of block 6609/5 in the Trænabanken area, off\r\nshore Mid Norway. The main objective was Late Triassic - Early Jurassic sand\r\nbodies at a prognosed depth of 3600 m. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 6609/5-1 was spudded with the\r\nsemi-submersible installation West Vanguard on 3 November 1984 and drilled to TD at 3600 m in the Triassic Red Beds. Few technical problems occurred during\r\nthe drilling period. The well was drilled with spud mud down to 820 m, with\r\ngypsum/polymer mud from 820 m to 3115 m, and with gel/lignosulphonate mud from\r\n3115 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eTop Cretaceous was encountered at 2132 m.\r\nGrey brownish sediments of the Early Cretaceous were found unconformable on reddish\r\nLate Triassic sediments at 3066 m. Early Cretaceous sand and silt layers had indications\r\nof hydrocarbons at a depth of 2195 m. Similar indications were seen in a silt at\r\n2580 m to 2595 m, some thin sandstones at 2856 to 2904, and a possibly\r\nCenomanian to Turonian age sand at 2987 m. Fluorescence and cut was observed on\r\nthin sandstones in the core at 3009 m. Further spots of weak shows were\r\nobserved on several cuttings and SWC sandstone samples from the Triassic\r\nbetween 3154 m and 3496 m. Logs displayed that all observed shows were residual\r\nhydrocarbons. \u003c/p\u003e\r\n\r\n\u003cp\u003eOne core was cut from 3009 m to 3020 m. No\r\nwire line fluid samples were taken in the well.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 5 January 1985 as dry with shows.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was performed.\u003c/p\u003e\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"439","properties":{"OBJECTID":439,"wlbNpdidWellbore":446,"wlbName":"34/10-22","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 34/10-22 was drilled on the Gullfaks\r\nField to test for possible shallow gas around the planned position of the\r\nGullfaks A platform.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 34/10-22 was spudded with the\r\nsemi-submersible installation on 25 October 1984 and drilled to TD at 579 m in\r\nPliocene sediments in the Nordland Group. No significant problem was\r\nencountered in the operations. The well was drilled with water based mud\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003ePliocene sediments were encountered at\r\n292 m, based on the logs. Four Pliocene sand layers were penetrated, and the\r\ntwo shallowest, at 310-315 m and 393-396 m, were gas bearing. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eEight core runs were attempted and a\r\ntotal of 22.2 m core was recovered in four cores. Wire line logging at TD was\r\nperformed. The bottom hole temperature 3 hours after circulation was 23.3 deg\r\nC. No fluid samples were taken.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was permanently abandoned on 5\r\nNovember 1984.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eTesting\u003c/span\u003e\u003c/b\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo drill stem test was performed.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"440","properties":{"OBJECTID":440,"wlbNpdidWellbore":447,"wlbName":"31/3-3","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThe wildcat well 31/3-3 was drilled on a\r\nstructure east of the Troll Field. The structure, which is deeper than the\r\noil/water contact proved in the Troll Field area, is defined on the Top\r\nSognefjord Formation and situated on a rotated fault block compartment dipping\r\ngently to the east. The main objective of the well was to test the Late\r\nJurassic sandstones, which were gas and oil bearing in the Troll Field. A\r\npossible stratigraphic trap in the Early Cretaceous sequence and small closures\r\nof the Brent Group and Statfjord Formation were secondary targets. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 31/3-3 was spudded with the\r\nsemi-submersible installation Treasure Saga on 13 October 1984 and drilled to\r\nTD at 2573 m in the Early Jurassic Statfjord Formation. No major problems\r\noccurred due to drilling. The well was drilled using spud mud down to 406 m,\r\nwith KCl/polymer from 406 m to 1630 m, with CaCO3 mud from 1630 m to 2112 m,\r\nand with gel/lignosulphonate from 2112 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eNo reservoir rock was encountered in the\r\nEarly Cretaceous. In the Jurassic a 152 m thick sequence of Sognefjord\r\nFormation consisting of several stacked coarsening upward sand sequences was\r\npenetrated. The Statfjord Formation consisted of alternating sandstones and\r\nclaystones with traces of limestone, mica and coal fragments. The only trace of\r\nhydrocarbons in the well were two very weak shows, possibly dope contamination,\r\nin cores no 3 and 5 in the Sognefjord Formation. Seven conventional cores were\r\ncut, one in the lower part of the Cromer Knoll Group and the last six in the\r\nLate Jurassic Sognefjord and Heather Formations. Totally 168.5 m were cut with\r\na recovery of 166.5 m (99%). No fluid samples were taken.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 18\r\nNovember 1984 as a dry well.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was performed\u003c/p\u003e\r\n\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"441","properties":{"OBJECTID":441,"wlbNpdidWellbore":448,"wlbName":"7/8-4","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 7/8-4 was drilled on the\r\nnorthern flank of the Central Graben. The prospect was a\r\nstructural/stratigraphic trap situated on the north flank of a high standing\r\nTriassic fault block. The objective was to test the hydrocarbon potential of a\r\nprognosed Late Jurassic sand body at 3840 m. Isolated sands within the Triassic\r\nwere also postulated as hydrocarbon traps and potential secondary targets.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 7/8-4 was spudded with the\r\nsemi-submersible installation Nortrym on 11 December 1984 and drilled to TD at\r\n4400 m in Early Triassic sandstones and shales of the Smith Bank Formation. The\r\noverall operation took 72 days from spud. Problems with gumbo and keeping the\r\nhole clean were experienced. A weighted KCl polymer mud was used to keep the\r\nhole open and prevent shale spalling. From 4192 m onwards, problems of tight\r\nhole was experienced with the drill string becoming permanently stuck at 4400\r\nm. Differential sticking was thought to be the problems, so the mud weight was\r\nreduced to compensate for this. While attempting to free the pipe the well\r\nstarted to flow but this was quickly stopped by raising the mud weight. While\r\npulling out of the hole the drill pipe got stuck with the bit at 4382 m. The\r\npipe was unscrewed at 4250 m and during fishing operations two more sections of\r\npipe were lost in the hole, one with the top at 4192 m, the other at 4183 m.\r\nThe operator then decided on a sidetrack, and the hole was cemented back to\r\n4130 m and a sidetrack was kicked off from 4140 m. Eleven days were lost due to\r\nthe plug back and sidetrack operation. The well was drilled with seawater down\r\nto 619 m and with KCl polymer mud from 619 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eTwo cores were cut from 3825.5 m to 3859\r\nm in what was believed to be the Ula sandstone of the Late Jurassic, the\r\nprimary objective. Subsequent analysis revealed the Lower Cretaceous to\r\nunconformably overlie Middle Triassic formations with no Jurassic rocks present\r\nat this","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"442","properties":{"OBJECTID":442,"wlbNpdidWellbore":449,"wlbName":"6407/9-2","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eAppraisal well 6407/9-2 was the second\r\nwell in the Northern part of the Draugen Discovery on the Haltenbanken. The\r\nmain objectives of the appraisal were to improve estimation of oil in place; to\r\nevaluate the reservoir quality and sand development on the Northern flank of\r\nthe structure; calibration of the seismic time pick and velocity model; and to\r\nevaluate the oil deliverability and water injection characteristics. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eAppraisal well 6407/9-2 was spudded with the\r\nsemi-submersible installation Borgny Dolphin on 18 November 1984 and drilled to\r\nTD at 1865 m in the Early Jurassic Tilje Formation. The well was drilled with\r\nseawater and bentonite down to 813.5 m and with KCl/Polymer mud from 813.5 m to\r\nTD. No shallow gas was encountered.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe Rogn Formation came in twenty m below\r\nprognosed depth at 1650 m. It consisted of an overall coarsening upwards sand\r\nsequence and contained an oil column of 12.5 m down to an oi1/ water contact at\r\n1663.5 m. The calculated porosity was fairly constant throughout the reservoir\r\nat approximately 27%, while measured permeability decreased from up to 5 Darcy\r\nin the oil-bearing interval down to 20 mD towards the base of the reservoir.\r\nEight conventional cores were cut from 1638 m to 1706.5 m. Several runs were\r\nmade with the RFT: the reservoir pressure measured was hydrostatic, 2392 psia\r\nat 1625 m. No down hole fluid sample was recovered due to repeated plugging of\r\nthe sampling probe.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 2\r\nFebruary as an oil appraisal\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eTwo DST tests were performed. The water\r\nzone was perforated from 1670 to 1675.5 m. An eight hours water injection test\r\nat rates up to 8000 b/d did not reveal any immediate problems related to\r\ninjection of unfiltered clean seawater. After the water zone test the oil zone\r\nwas perforated from 1651 to 1657 m. The well was gravel packed and rates up to\r\n1177 Sm3/day (7400 stb/d) of 40 deg API o","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"443","properties":{"OBJECTID":443,"wlbNpdidWellbore":450,"wlbName":"6/3-1","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 6/3-1 was drilled on the\r\nPi-structure in the northwestern part of the block. The well is situated less\r\nthan 1 km from the UK-Norwegian median line, where the UK Drake Field, an\r\noil/gas field in UK block 2215was discovered close to the median line. Well\r\n6/3-1 was designed to test possible hydrocarbon accumulations at different\r\nlevels. The main target was Jurassic and Triassic sandstones. Secondary targets\r\nwere Paleocene sandstones (Heimdal Formation), and Late Cretaceous\r\nporous/fractured chalk.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was spudded with the\r\nsemi-submersible installation Deepsea Bergen 2 November 1984 and drilled to TD\r\nat 3560 m in the Triassic Skagerrak Formation. Drilling of the well proceeded\r\nwithout significant problems, but five and a half rig days were spent waiting\r\non weather. The well was drilled with gel/seawater to 520 m, with\r\ngypsum/polymer from 520 m to 2926 m, and with lignite/lignosulphonate from 2926\r\nm to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eTarget reservoir sandstones of\r\nJurassic/Triassic age came in at 2965 m with oil and gas/condensate. A\r\nhydrocarbon column of 72 m was proven with oil/water contact at 3037 m. FMT\r\ngradients and oil stain on cores indicated a GOC at 3013 m. Secondary target\r\nsand (Heimdal Formation) was not found. Logs and shows indicated hydrocarbons\r\nin Late Cretaceous chalk/limestone, most strongly from 2900 m to 2925 m, but\r\ntest of this interval was negative. FMT pressure measurements in the larger\r\ninterval from 2804 m to 2918.5 m in the chalk were all unsuccessful and showed\r\na tight formation. Eight cores were cut in the well from 2968 m to 3116.5 m.\r\nSegregated FMT samples were taken at 3021.5 m (0.87 g/cm3-oil and gas), at\r\n3007.5 m (0.780 g/cm3-condensate, gas, and mud filtrate), at 3016 m (oil, mud\r\nfiltrate, and gas), at 2992 m (0.77 g/cm3-condensate, mud filtrate, and gas),\r\nat 2998.5 m (condensate and gas), and at 2966 m (0.77 g/cm3-condensate, mud\r\nfiltrate, and gas). \u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permane","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"444","properties":{"OBJECTID":444,"wlbNpdidWellbore":451,"wlbName":"16/3-1","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 16/3-1 was drilled on the Utsira\r\nHigh in the North Sea. The objectives were to investigate Paleocene sand pinch\r\nout, the weathered top of the Cretaceous chalk and Jurassic sandstone.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 16/3-1 was spudded with the\r\nsemi-submersible installation Polyglomar Driller on 31 January 1976 and drilled\r\nto TD at 453 m in Pliocene sediments. The well was drilled with seawater and\r\ngel. \u003c/p\u003e\r\n\r\n\u003cp\u003eDue to progressive tilting of the BOP\r\nstack the well was junked and abandoned 10 days later, on 10 February 1976.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was performed\u003c/p\u003e\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"445","properties":{"OBJECTID":445,"wlbNpdidWellbore":452,"wlbName":"30/9-4 S","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 30/9-4 S was drilled on the\r\nB-structure on the southeast flank of the Oseberg Field in the North Sea. The\r\nstructure is an elongated rotated fault block bounded by faults in all\r\ndirections. The Brent Group is truncated by the Base Cretaceous unconformity,\r\nand this well was expected to go directly from Cretaceous to the Ness\r\nformation. The objectives of the well were to find hydrocarbon accumulations in\r\nthe Brent Group, secondary in the Statfjord Group. The well was designed to\r\npenetrate the Brent Group in a position where the sand in the Ness Formation is\r\npreserved. The well was deviated westwards at an angle of approxi­mately 40°.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 30/9-4 S was spudded with\r\nthe semi-submersible installation Treasure Seeker on 22 November 1984 and\r\ndrilled to TD at 4303 m (3577 m TVD) in the Early Jurassic Eiriksson Formation.\r\nNo significant problems were encountered during operations. The well was\r\ndrilled with spud mud down to 222 m, with seawater/gel from 222 m to 630 m,\r\nwith oil based Safemul mud from 630 m to 3297 m, with NaCl/polymer mud from\r\n3297 m to 3680 m, and with oil based Safemul mud from 3680 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well 30/9-4 encountered two separate\r\nhydrocarbon reservoirs in the Middle Jurassic Brent Group. Pressure data\r\nindicated no communication between the two hydrocarbon columns. The Tarbert\r\nFormation and uppermost Ness Formation (3295-3379 m, 2773-2841 m TVD)\r\nsandstones were found to be gas bearing, but no definite gas/fluid contacts\r\nwere evident. Net pay in the gas zone was calculated to be 27.6 m (22.1 m TVD),\r\naverage porosity 18.6%, and the average water saturation 20.9%. The Ness\r\nFormation (3379-3551 m, 2841-2979 m TVD) proved to be oil bearing, but again no\r\nOWC could be discerned. Net pay ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"446","properties":{"OBJECTID":446,"wlbNpdidWellbore":453,"wlbName":"34/10-29","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 34/10-29 \u00A0was drilled on the\r\nGullfaks Field to investigate and drain possible shallow gas sands between 342\r\nto 347 m at the platform A location on the Gullfaks Field. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eDuring anchoring a damaged fairlead for\r\nanchor no 8 was discovered and the rig had to be towed to land for repair. Nine\r\ndays were lost. Also the rough weather with wind speed up to 36 - 42 m/s and\r\nwaves reaching 16 m caused significant WOW down-time. Well 34/10 was spudded\r\nwith the semi-submersible installation West Venture on 27 December 1985 and\r\ndrilled to TD at 482 m in Pliocene sediments in the Nordland Group. Apart from\r\nWOW no significant down-time or technical problem was encountered in the\r\noperations. The well was drilled with water based mud.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eTop Pliocene was encountered at 291 m. The\r\nwell penetrated sand in the interval 344 m to 348 m. The upper 0.5 m was gas\r\nbearing. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThree short cores were cut with junk\r\ncatcher in the interval 344 m to 347 m. A total of ca one meter clay with variable\r\nsilt/sand/pebbles was retrieved. No wire line fluid samples were taken.\r\nCuttings samples were taken every 5 m from 275 m to TD. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was permanently abandoned on 26\r\nJanuary 1986.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eTesting\u003c/span\u003e\u003c/b\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was perforated and tested in the\r\ninterval 344 m to 346 m, with nitrogen cushion. In the first flow period the\r\nwell produced gas at a rate of ca 25000 Sm3/day. A perforation wash was\r\nperformed, and then acid treatment in order to increase the flow. No further flow\r\nwas achieved and the well was killed.\u003c/span\u003e\u003c/p\u003e\r","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"447","properties":{"OBJECTID":447,"wlbNpdidWellbore":455,"wlbName":"34/7-4","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 34/7-4 was drilled on the Snorre E\r\nstructure in the northern part of block 34/7. The primary objectives were to\r\nfurther appraise the reservoir potential of the Statfjord Formation in the\r\nE-structure extension of the Snorre Discovery, to test the oil/water contact\r\nfound in wells 34/7-1, and to test the reservoir quality in this area. A\r\nsecondary objective was to test the reservoir potential in the upper Lunde\r\nFormation, which contain oil in an up-dip location.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 34/7-4 was spudded with\r\nthe semi-submersible installation Treasure Saga on 19 November 1984 and drilled\r\nto TD at 3115 m in the Late Triassic Lunde Formation. No significant problems\r\noccurred during drilling of the well. The well was drilled with spud mud down\r\nto 963 m, with gypsum/polymer mud from 963 m to 2759 m, and with\r\nlignosulphonate mud from 2759 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eExcept for the sandy Utsira Formation\r\n(Late Miocene/Pliocene) and an Early Eocene sandstone unit (1625-1664 m) in the\r\nlower part of the Hordaland Group, the well proved mainly claystones down to\r\nthe Early Jurassic Statfjord Formation at 2535.5 m. The Statfjord Formation was\r\n92 m thick and was oil bearing down to claystones in top Lunde Formation at 2627.5\r\nm. No definite oil-water contact was seen. The N/G ratio in the Statfjord\r\nFormation was 0.26. The average porosity was 20 % and the average water\r\nsaturation was 44%. The Lunde Formation proved mainly a claystone/siltstone\r\nsequence in the upper part, while the lowermost 265 m proved a sequence of\r\nalternating sandstones and claystones with limestone stringers. Of this\r\nsequence some 123 m can be considered as net. The Lunde Formation reservoir was\r\nwater bearing. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThree co","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"448","properties":{"OBJECTID":448,"wlbNpdidWellbore":456,"wlbName":"7120/6-1","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 7120/6 1 was drilled in the\r\nmiddle eastern part of the block, on a structure comprising an east-west horst\r\nblock extending into blocks 7121/4 and 7121/5 to the east, and with a central\r\neast west oriented fault at Middle Jurassic level. The primary objective of the\r\nwell was to test Middle Jurassic sand sequences in the Stø Formation. A further\r\nobjective was to evaluate geologic trends in stratigraphy, structure and\r\nreservoir development in a northerly direction in the Hammerfest Basin. The well was prognosed to be drilled into rocks of Triassic age\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was spudded with the semi\r\nsubmersible installation Treasure Scout 2 February 1985 and drilled to TD at\r\n2820 m in Late Triassic rocks (Tubåen Formation). No significant problems\r\noccurred during drilling. It was drilled and tested in 90 days with only 4.4\r\ndays down time. Of these 3.2 days were wait-on-weather (WOW). The well was\r\ndrilled with spud mud down to 815 m and with KCl/polymer mud from 815 m to TD. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe well encountered hydrocarbon bearing\r\nJurassic sands of the Stø Formation from 2385.5 m to 2469.5 m. The interval\r\nfrom 2385.5 to 2427 m was gas bearing and from 2427 to 2443 m oil bearing. In\r\nthe interval 2559 - 2800 m (Tubåen Formation), thin gas bearing sandstone\r\nstringers were encountered. This interval spanned the Jurassic-Triassic\r\nboundary, and in the lower intervals below 2660 m net pay was associated with\r\nthin interbedded coals. Weak oil shows were observed in claystones in the\r\nCretaceous below 2176 m. Good oil shows in sandstones were recorded throughout\r\nthe hydrocarbon bearing zone and down to 2500 m. Below this level oil shows\r\nwere in general associated either with mud stones or with coal seams and\r\nfragments.\u003c/p\u003e\r\n\r\n\u003cp\u003eGeochemical studies indicated that the\r\nTertiary and Cretaceous sediments were immature. Above 2300 m there were\r\nalternating poor source rocks for oil and gas and very good oil-prone source\r\nrocks. The top J","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"449","properties":{"OBJECTID":449,"wlbNpdidWellbore":457,"wlbName":"30/2-2","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 30/2-2 was drilled on the\r\nMokkukalven Fault Complex north of the Oseberg Field in the North Sea.\u003c/span\u003e\u003cspan\r\nlang=EN-GB\u003e \u003c/span\u003e\u003cspan lang=EN-US\u003eThe objective was \u003c/span\u003e\u003cspan lang=EN-GB\u003eto\r\ntest possible hydrocarbon accumulations in the Huldra Field, on a structural\r\nhigh that is separated from Huldra discovery well 30/2-1 with significant\r\nfaults. Well 30/2-1 encountered a 119 m gas column in the Brent Group with a\r\ndown-to contact at 3793 m. The actual gas/water or oil/water contact could not\r\nbe established. The main target for 30/2-2 was the Brent Group, believed to be\r\nsome 70 m deeper than the gas column in 30/2-1.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 30/2-2 was spudded with\r\nthe semi-submersible installation Dyvi Delta on 19 December 1984 and drilled to\r\nTD at 4172 m in the Early Jurassic Drake Formation. When doing the reservoir\r\nlogging, a radioactive part of the logging tool was left in the hole. This\r\naccident caused a sidetrack from 3894 m KB to TD. The sidetrack ran parallel to\r\nthe original hole at a distance of approximately 20 m. The intention was to\r\ndrill 50 m into the Statfjord Formation, but the well was finished in the Drake\r\nFormation due to hole conditions. The well was drilled with spud mud down to\r\n214 m, with gel/seawater from 214 m to 1023 m, with gypsum/CMC mud from 1023 m\r\nto 3802 m, and with gel/lignosulphonate from 3802 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eGas bearing Brent sandstone was\r\nencountered at 3935 m, with the gas-water contact somewhere in the interval\r\n3975 - 4080 m. No distinct contact was possible to recognize from logs or\r\nshows, but later geochemical analyses of the corers indicated a contact at ca\r\n3984 m. Fluorescence indicating shows was first recorded on claystone/limestone\r\ncuttings in the interval 2204 m to 2267 ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"450","properties":{"OBJECTID":450,"wlbNpdidWellbore":458,"wlbName":"34/7-5","wlbHistory":"\r\n\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 34/7-5 is located in the Statfjord Øst\r\narea of the Northern North Sea. The primary objectives of the well were to test\r\nthe reservoir potential of the Brent Group, and to determine if the oil/water\r\ncontact is the same as that found in the 33/9-7 Statfjord Øst discovery well drilled\r\nto the south southwest of this well in the neighbouring block, but on the\r\nassumed same structure. A secondary objective was to test the reservoir\r\npotential of the Statfjord Formation.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 34/7-5 was spudded with the\r\nsemi-submersible installation Treasure Saga on 17 January 1985 and drilled to\r\nTD at 3146 m in the Late Triassic Lunde Formation. Drilling proceeded without\r\nsignificant problems. The well was drilled with spud mud down to 930 m and with\r\ngypsum/polymer mud from 930 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eTrace oil shows appeared in sandstone lamina\r\nin the Cretaceous from about 2380, limestones had shows from about 2488 m. The Brent\r\nGroup reservoir came in at 2502 m, approximately 60 m deeper than prognosed. Hydrocarbons\r\nwere encountered in the upper section belonging to the Ness Formation. The\r\noil/water contact could not be defined from pressure data. From shows on cores\r\nand the well logs an OWC could be placed at approximately 2521 m, in accordance\r\nwith the results from well 33/9-7. Below the OWC oil shows on sandstone\r\ndecreased gradually from 2523 m until they vanished at 2616 m. The Statfjord\r\nFormation was dry. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eEleven cores were cut. Cores 1 to 10 were\r\ncut from 2508 m to 2633 m in the Brent Group and the uppermost part of the\r\nDrake Formation. Core 1, from 2508 to 2510 gave no recovery. The core depths\r\nfor Cores 2 to 10 were from 0.5 m to 2.2 m short of logger's depth. Core 11 ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"451","properties":{"OBJECTID":451,"wlbNpdidWellbore":459,"wlbName":"2/1-8","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 2/1-8 was drilled on the Cod Terrace\r\non the margin between the southern Vestland Arch and the Central Trough in the\r\nNorth Sea. The objective was to evaluate the Late Jurassic Gyda member reservoir\r\nsandstone (the "2/1-3 Sand") in the south-eastern part of the field.\u003cb\u003e\r\n\u003c/b\u003e\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 2/1-8 was spudded with the\r\njack-up installation Neddrill Trigon on 28 July 1985 and drilled to TD at 4151\r\nm (4159 m Logger's Depth) in the Triassic Skagerrak Formation. The well was\r\ndrilled with spud mud down to 635 m, and with KCl/polymer mud from 635 m to 3474\r\nm. At this depth the drill string got stuck while pulling out of the hole. It\r\nwas freed after pumping pipelax into the hole. Following the pipelax pill and\r\ndown to 3888 m the mud contained 1.0 - 2.5% oil. Drilling commenced with an\r\noil-free KCl/polymer mud from 3888 m to TD. Below 2000 m logger's depth = driller's\r\ndepth + 8 m. Above this depth there is no discrepancy. In the following all\r\nquoted depths are logger's depths.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eA 40 m thick Gyda member sandstone was penetrated\r\nat a depth of 3899.5 m. Cores from the reservoir proved a coarsening up\r\nsequence of very fine to medium grained sandstone. The reservoir was oil\r\nbearing throughout. Oil stain and gas bleed were observed in cores of very fine\r\nsandstones and siltstones from the underlying Farsund and Haugesund Formations.\r\nThe Ula Formation at 4037 m was 26 m thick and water bearing. Traces of hydrocarbons\r\nwere recorded from 3818 - 3821 m in the Early Cretaceous Åsgard Formation.\r\nThese possibly result from leakage, up a minor fault, from Late Jurassic rocks.\r\nThere were no significant hydrocarbon shows in any other section of the well.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThree cores w","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"452","properties":{"OBJECTID":452,"wlbNpdidWellbore":460,"wlbName":"30/3-4","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eAppraisal well 30/3-4 was drilled on the Veslefrikk Field.\r\nThe primary objectives of the well were to investigate possible oil\r\naccumulations in sandstones in Ness and Etive Formations, and to determine the\r\noil/water contact. Secondary objective was sandstone of the Early Jurassic\r\nDunlin Group.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 30/3-4 was spudded with the\r\nsemi-submersible installation Deepsea Bergen on 5 February 1985 and drilled to\r\nTD at 3287 m in Early Jurassic sediments of the Statfjord Formation. Drilling\r\nwent without problems to a depth of 1788 m. While running the 13 3/8"\r\ncasing a wedge got stuck in the BOP and locked the casing. A technical\r\nsidetrack was decided. The sidetrack was kicked off from 790 m, and drilled to\r\n1792 m. An attempt to set 13 3/8" casing at this depth was unsuccessful,\r\nas the shoe got stuck at 1178 m. The casing was cut at 872 m and a second\r\ntechnical sidetrack was kicked of from 630 m. The problems encountered while\r\nrunning casing might have been caused by differential pressure between the\r\nUtsira sand and a sand at 1700 m. A total of 4 weeks was spent on the 17\r\n1/2" section before the 13 3/8" casing was finally in place. Drilling\r\nto TD proceeded without further problems. The interval below 3131 m was drilled\r\nwith turbine. The well was drilled with seawater and hi-vis pills to 248 m,\r\nwith gel/seawater from 248 m to 606 m, and with KCl/polymer mud in the 17\r\n1/2" section from 606 m to 1605 m. In the final 17 12/2" sidetrack\r\nfrom 630 m "Torq Trim" and 7% diesel was added to the mud. The 12\r\n1/4" section from 1605 m to 2812 m was drilled with KCl/polymer mud, and\r\nthe 8 1/2" section from 2812 m to TD was drilled with\r\nLignite/Lignosulphonate mud. \u003c/p\u003e\r\n\r\n\u003cp\u003eHydrocarbons were encountered in both Ness and Etive Formations and in the secondary target, the Cook Formation. Top reservoir in\r\nthe Brent Group is at 2843 m, and the oil/water contact is at 2930 m. Top Cook\r\nF","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"453","properties":{"OBJECTID":453,"wlbNpdidWellbore":461,"wlbName":"7121/4-2","wlbHistory":"\r\n\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 7121/4-2 was drilled on a\r\nstructure separate from and North of the Snøhvit Field in the Hammerfest Basin.\r\nThe main objective was to test possible hydrocarbon accumulations in Middle to\r\nEarly Jurassic sandstones. Prognosed TD was at 2800 m in rocks of Triassic age.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 7121/4-2 was spudded with\r\nthe semi-submersible installation West Vanguard on and drilled to TD at 2800 m\r\nin the Late Triassic Fruholmen Formation. Drilling proceeded without\r\nsignificant problems to 2460 m, in the middle of an Oxfordian shale, where\r\ncavings caused some tight spot problems while setting casing. Rough weather\r\ncaused some delay in the drilling schedule. The well was drilled with bentonite\r\nspud mud down to 417 m, with pre-hydrated bentonite from 417 m to 900 m, with\r\ngypsum/\u003ca name=\"OLE_LINK1\"\u003elignosulphonate \u003c/a\u003efrom 900 m to 2455 m, and with\r\nlignosulphonate from 2455 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eReservoir top, Stø Formation, was\r\nencountered at 2480 m. RFT tests, samples and log responses indicated gas down\r\nto a gas/water contact at 2517 m. The gas zone consists of an interbedded\r\nsandstone/shale sequence with fair/poor reservoir properties. Fluorescence and\r\ncut was recorded throughout the cored section, which included the reservoir\r\nsection. In addition oil stain was seen on a core from 2541.5 m to 2551 m.\r\nThere was also a small gas zone at 2701.5 m to 2705 m in the Tubåen Formation.\r\nChromatographic analysis showed a significantly drier gas here than in the main\r\nreservoir. Triassic, Rhaetian age sandstone was encountered from 2737 m to TD.\r\nBasement was not seen. Seven cores were cut in from 2463 m in the Fuglen\r\nFormation to 2597.5 m in the Nordmela Formation. The recovery was 134.3 m.\r\nSegregated RFT samples were taken at 24","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"454","properties":{"OBJECTID":454,"wlbNpdidWellbore":462,"wlbName":"6506/12-2","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 6506/12-2 is located on the\r\nHalten Terrace off shore Mid Norway. Its primary objective was to test possible\r\nhydrocarbon accumulations in Middle and Early Jurassic sandstones on the Beta\r\nProspect at an antiform structure in the southeastern part of the block.\r\nSecondary objectives were Early Jurassic and Triassic sandstones, in addition\r\nto sands within the Coal Beds. Prognosed TD was at 4380 m in the Jurassic coal\r\nsequence, or in Middle Jurassic sandstones at 3902 m.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 6506/12-2was spudded with the\r\nsemi-submersible installation Ross Isle on 12 February 1985 and drilled to TD\r\nat 955 m in Pliocene sediments (Nordland Group). A pilot hole was drilled to\r\n955 m and logs were run. Shallow gas was detected on log readings at 572 m, and\r\ngas peaks of 6.9% at 573 m and 6% at 580 m confirmed this observation. Water\r\nflow and lost circulation caused problems, but was stabilised with LCM pills.\r\nThe well was drilled with seawater and pre-hydrated bentonite. \u003c/p\u003e\r\n\r\n\u003cp\u003eProblems with a wear bushing caused the\r\nabandonment of the well on 28 February 1985. Spudding and drilling of\r\nreplacement well 6506/12-3 started two days later.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was performed\u003c/p\u003e\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"455","properties":{"OBJECTID":455,"wlbNpdidWellbore":463,"wlbName":"25/1-7","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 25/1-7 was drilled on the main Frigg\r\nstructure close to the UK border. The Frigg Field was discovered by well 25/1-1\r\nin 1971. Production from the field started in 1977. Well 25/1-7 was designed to\r\nmonitor the remaining producible gas accumulation in the Frigg Field, and to\r\ndetermine the Frigg Formation heterogeneity north of the producing platforms\r\nincluding the integrity and nature of the barrier between the Frigg sands and\r\nthe Cod aquifer (Hermod Formation). The main objectives were to observe changes\r\nin gas/oil and oil/water contacts as the Frigg Field is produced, and to core\r\nthe whole Frigg and Balder Formations. The prognosed depth was 2700 m.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 25/1-7 was spudded with\r\nthe semi-submersible installation Byford Dolphin on 8 March 1985 and drilled to\r\nTD at 2719 m in the Late Cretaceous Jorsalfare Formation. Drilling proceeded\r\nwithout significant problems. The well was drilled water based.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe Frigg Formation came in at 1919 m, 34\r\nm deeper than prognosed. The Frigg Formation in this well consist of an upper\r\npart down to 1977 m with fine grained shale interbedded with sand layers; a massive\r\nfine to very fine sand, occasionally micaceous and glauconitic, slightly shaly down\r\nto 2044 m; and a basal part consisting of sand and sandstone (calcareous),\r\noccasionally micaceous, with shale and silt layers down to 2180 m. The oil/water\r\nand gas/oil contacts were in the upper part and were difficult to define from\r\nthe logs due to the shale. The following contacts were however defined for\r\nlater reference: base of deepest gas at 1964.5 m (1938.7 m MSL), top of highest\r\noil at 1965.8 m (1940 m MSL), and top of highest water at 1976.5 m (1950.7 m\r\nMSL). Residual oil was seen down to 1999.5 m.\u003c/span\u003e\u003c/p","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"456","properties":{"OBJECTID":456,"wlbNpdidWellbore":464,"wlbName":"6507/7-2","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well 6507/7-2 was drilled in the\r\nnorthern part of the Haltenbanken area, some 190 km west of the Norwegian\r\ncoast. It was drilled to evaluate the "B" prospect in the intensely\r\nfaulted zone that lies at the intersection of the Nordland Ridge in the\r\nnortheast and the Halten Terrace in the south. The prospect was in a southward\r\nplunging horst block formed by a Late Jurassic tensional fault system. The main\r\nreservoir interval was anticipated to be the Lower Jurassic sandstone of the\r\nAldra (Tilje) Formation.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 6507/7-2 was spudded with\r\nthe semi-submersible installation Nortrym on 25 February 1985 and drilled to TD\r\nat 3262 m in Late Triassic sediments of the Åre Formation. No significant\r\nproblems occurred during drilling operations, which went very much according to\r\nschedule. The seven-test program was however delayed approximately two weeks\r\ndue to a premature firing of the Baker Tubing-Conveyed Perforating Guns while\r\nrunning in for DST 4. This necessitated the running of a protective string of\r\n7" casing to cover the perforations (1062.5m to 1072.5m) and enable the\r\ntesting program to be completed. Additional time was lost due to pulling and\r\nrepairing the BOP stack after running the protective casing string. The well\r\nwas drilled with sea water down to 1030 m and with gypsum mud from 1030 m to\r\nTD.\u003c/p\u003e\r\n\r\n\u003cp\u003eShetland Group sediments were resting\r\ndirectly on the Fangst Group, confirming heavy erosion at the crest of the\r\nstructure as prognosed. The oldest dating of the Shetland Group was Santonian\r\nage, in sediments ca 5 m above top Fangst Group, while the youngest Fangst\r\nGroup sediments were dated Toarcian-?Aalenian. At 2198 meters gas levels rose,\r\nindicating the top of the Jurassic sediments. Associated with the gas show was\r\na rare dull-gold fluorescence on cuttings; however, no cut or staining was\r\nevident. The MWD gave little indication of sand through the Fangst Group and\r\nvery little sand","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"457","properties":{"OBJECTID":457,"wlbNpdidWellbore":465,"wlbName":"34/7-6","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 34/7-6 was drilled centrally on the\r\nSnorre Field in the Tampen Spur area of the North Sea. The objectives were to\r\ntest the reservoir quality of the Statfjord Formation and the extent of the low\r\nGOR oil encountered in the 34/7-3 and 34/7-4 wells. Further objectives were to\r\ntest the proposed subdivision and reservoir characteristics of the Triassic\r\nLunde and Lomvi formations.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 34/7-6 was spudded with\r\nthe semi-submersible installation Treasure Saga on 17 March and drilled to TD\r\nat 3685 m in the Triassic Teist Formation. No significant problem was\r\nencountered in the drilling phase. After DST 1 parts of the test string stuck,\r\nleaving a fish with top at 2533 m in the hole. The fish was pushed down 12 m to\r\ngive space for further testing. The well was drilled with spud mud down to 965\r\nm, with gypsum/polymer mud from 965 m to 3015 m, and with Drispac/Ligcon mud\r\nfrom 3015 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eApart from the sandy Utsira Formation of Late\r\nOligocene - Pliocene age, and sandstone units of Early Oligocene age (1215 -\r\n1280 m) and Middle - Late Eocene age (1370 - 1420 m) within the Hordaland\r\nGroup, the upper section down to the Jurassic proved mainly claystones. The\r\nJurassic consists of a silty Dunlin Group and a sandy Statfjord Group. The\r\nTriassic had sandstones alternating and interbedded with claystones down to TD.\r\n\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eSilty laminae in the Shetland Group had\r\ntraces of shows from about 2110 m. These were described as gold yellow\r\nfluorescence with no cut. From 2155 m and down to 2500 m silt and sandstone\r\nshow golden yellow fluorescence and slow streaming cloudy yellow fluorescence\r\ncut. Occasionally light brown staining and weak odour are observed from 2500 m.\r\nH","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"458","properties":{"OBJECTID":458,"wlbNpdidWellbore":466,"wlbName":"31/6-8","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eAppraisal well 31/6-8 was drilled in the\r\nsouth-west corner of the Troll East gas province, 50 m due north of well\r\n31/6-7, which was junked and abandoned for technical reasons. The main\r\nobjectives were to determine the lateral extent of the reservoir, to determine\r\nthe fluid contacts in the Sognefjord Formation, and to obtain the best possible\r\nseismic correlation within the reservoir from well 31/6-1. In addition, an\r\nelaborate testing program was planned to obtain a number of reservoir\r\nengineering parameters.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 31/6-8 was spudded with the\r\nsemi-submersible installation Treasure Seeker on 14 April 1985 and drilled to\r\nTD at Drilling the well proceeded without significant problems. The interval\r\ndown to setting depth for 20" casing was not logged, as this interval was\r\nconsidered covered by logs from well 31/6-7. The well was drilled with spud mud\r\ndown to 700 m, with KCl Polymer mud from 700 m to 1465 m, and with "drill\r\nin fluid" (NaCl, polymers, and CaCO3) from 1465 m to TD. An 8 m3\r\nImcospot/Pipelax pill was spotted at 2054 m to free the pipe, which was stuck. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe Sognefjord Formation (1507-1661 m)\r\nwas found gas bearing from 1507 m to 1573.5 m and oil bearing from 1573.5 to\r\n1578.5 m where the oil/water contact was found. The oil zone was determined\r\nfrom petrophysical evaluation, core plug saturations and segregated sample\r\nrecoveries. The hydrocarbon-bearing reservoir consisted of predominantly very\r\nfine to fine grained sandstones with some interbedded siltstones. The gross\r\nhydrocarbon column was 71.5 m and the net pay calculated to 67 m with an\r\naverage porosity of 33% and average water saturation of 16.2 %. No hydrocarbon\r\nindications were recorded above 1507 m or below 1579 m.\u003c/p\u003e\r\n\r\n\u003cp\u003eTwelve cores were cut in the Late to Middle\r\nJurassic Sognefjord and Heather Formations from 1489 m to 1700 m (148 m total\r\nrecovery). FMT segregated samples were taken at 1573.2 m (0.7 Sm3 gas, 0.5 l\r\nwater/","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"459","properties":{"OBJECTID":459,"wlbNpdidWellbore":467,"wlbName":"34/2-4","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 34/2-4 was drilled in the\r\nsoutheastern corner of block 34/2. The objective of the well was to test\r\npossible hydrocarbon accumulations in the middle and Lower Jurassic sandstones.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was spudded 22 March 1985 by the\r\nsemi-submersible rig West Venture, and drilled to TD at 4107 m logger's depth\r\n(4110 m MD RKB) in the Lower Jurassic Statfjord Formation. The well was drilled\r\nwith seawater and hi-vis pills down to 814 m and with gypsum/polymer mud from\r\n814 m to TD. No significant problems were encountered during drilling. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe lithology of the well corresponded\r\nvery well with that of well 34/2-2 R with no significant sandstones down to the\r\nLower Jurassic Cook Formation. The primary objective, a distal facies of the\r\nMiddle Jurassic Brent sandstone, was not seen in this well. Instead, a\r\nclaystone/shale sequence belonging to the Heather Formation was penetrated.\r\nSecondary target sandstones of the Lower Jurassic Cook and Statfjord Formations\r\nwere drilled proving water wet. Weak oil shows were seen between 3030 m and\r\n3740 m, with the most prominent shows in the 3245-3580 m interval. Oil shows\r\nwere generally associated with thin sandstones and siltstones in a generally\r\nargillaceous section. Occasional thin limestone and/or dolomite stringers also\r\nprovided oil indications. Geochemical analyses detected possible migrated\r\nhydrocarbons also in the Cook Formation. One core was cut with 58% recovery in\r\nthe interval 3827 m to 3846 m. No wire line fluid samples were taken. The well\r\nwas permanently abandoned as dry with weak shows on 11 June 1985.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was performed\u003c/p\u003e\r\n\r\n\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"460","properties":{"OBJECTID":460,"wlbNpdidWellbore":468,"wlbName":"6506/12-3","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e \r\n\u003cp\u003eWildcat well 6506/12-3 is a replacement\r\nwell for 6506/12-2, which was abandoned at 955 m due to technical problems. The\r\nnew well was designed to test the hydrocarbon potential of the Beta structure\r\nin the southeast part of the \u003c/p\u003e\r\n\r\n\u003cp\u003eblock. The main object was Middle\r\nJurassic sandstones, secondary targets were possible Cretaceous sands, Early\r\nJurassic sandstones and sandstones within the Coal Beds.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 6506/12-3 was spudded with the\r\nsemi-submersible installation Ross Isle, 47 m from the junked well 6506/12-2.\r\nIt was spudded on 2 March 1985 and drilled to TD at 4360 m in the Early\r\nJurassic Tilje Formation (formerly called the Aldra Formation). No significant\r\ntechnical problems occurred during the operations. From 0600 hours on 15 June,\r\nduring the testing phase, the rig was on strike for 13 days. The well was\r\ndrilled with seawater/gel down to 955 m, with gypsum/lignosulphonate mud from\r\n955 m to 3831 m, and with gel/lignosulphonate mud from 3831 m to TD. The shallow\r\ngas present at 572 m in 6506/12-2 was not encountered in 6506/12-3. \u003c/p\u003e\r\n\r\n\u003cp\u003eTop Middle Jurassic Garn Formation\r\n(formerly Tomma Formation) came in at 3822 m, 80 m above the prognosis. The\r\nEarly Jurassic Tilje Formation sandstone (Aldra Formation) came in at 4147 m. Hydrocarbons\r\nwere encountered both in the Middle and the Early Jurassic sandstones, with a\r\nhydrocarbon/water contact at 4216 m in the Tilje Formation. Late Cretaceous\r\nLysing sandstones at the top of the Cromer Knoll Group (Finnvær Group) was also\r\nhydrocarbon bearing. A total of 242 m of hydrocarbon bearing sands was proven.\r\nShows were only recorded in association with the hydrocarbon bearing sections.\u003c/p\u003e\r\n\r\n\u003cp\u003eA total of 289 m core was recovered in 15\r\ncores from the Garn, Not, Ile, Ror, and Tilje Formations between 3836 and 4269\r\nm. Six RFT runs were completed in the Early - Middle Jurassic section in well\r\n6506/12-3. A total of 47 pressure tests gave reliable results. In addition,\r\nsegreg","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"461","properties":{"OBJECTID":461,"wlbNpdidWellbore":469,"wlbName":"6407/9-3","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eAppraisal well 6407/9-3 was the third\r\nwell on the antiform structure of the Draugen Field in the Haltenbanken area.\r\nIt was placed on the crestal part of the structure, some four kilometres south\r\nof the discovery well. The main objectives of the well were to evaluate the\r\nlateral continuity and quality of the reservoir; to establish the velocity\r\ntrend in a North-South direction; to improve the volumetric estimate; and to\r\nevaluate the oil deliverability.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eAppraisal well 6407/9-3 was spudded with\r\nthe semi-submersible installation Borgny Dolphin 3 may 1985 and drilled to TD\r\nat 1868 m in the Early Jurassic Tilje Formation. Drilling proceeded without\r\nserious problems, except for the sections trough glacial deposits were boulders\r\ncaused minor problems. After setting 13 3/8" casing at 1601 m the RKB\r\ndatum was shifted one m to 26 m above MSL. Operations were interrupted for\r\nnearly 17 days from 13 June 1985 by a crew strike. Although amplitude anomalies\r\nindicated gas charged sands, no shallow gas was encountered. The well was\r\ndrilled with seawater and bentonite down to 781 m, with KCl mud from 781 m to\r\n1617 m, and with chalk mud from 1617 m to TD. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe top of the Rogn Formation was\r\npenetrated at 1630 m (1604 m SS) and the reservoir was oil bearing down to an\r\noil-water contact at 1664 m (1638 m SS), which is in line with the OWC observed\r\nin the other Draugen wells. The contact in this well was interpreted in the\r\ntransition between the good sands and the basal shales and was for that reason\r\nnot very clear. The average hydrocarbon saturation was calculated as 82% over\r\nthe 34 m oil column. Average porosity was 31% in this interval, of which 16.7 m\r\nhad a porosity above 32.5%. Prior to testing an FMT survey was carried out: the\r\nreservoir pressure measured was hydrostatic, 2395 psia at datum (1630 m SS).\r\nThe Garn Formation was penetrated from 1685 m to 1770 m and was water wet. Oil\r\nand oil shows were recorded in t","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"462","properties":{"OBJECTID":462,"wlbNpdidWellbore":470,"wlbName":"6507/11-3","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 6507/11-3 was designed to test the\r\nBeta Fault compartment of the Midgard Discovery off shore Mid Norway. The Beta\r\nsegment is a part of the Midgard horst. This horst is defined by NNV trending\r\nnormal faults. It is separated from the other compartments by a ENE trending\r\ncross fault and exhibits true vertical closure at Base Cretaceous level. The\r\nprimary target was reservoir rocks of the Middle Jurassic Fangst Group with the\r\nobjective to establish the GWC within a good sand and to perform a DST in a\r\nformation not previously being tested (the Ile Formation). The location was\r\nchosen relatively high on the structure in case the hydrocarbon contact for\r\nBeta was different from what was seen in the Alpha and Gamma structures. The\r\nwell should reach Triassic rocks or drill to 500 m below the coal reflector.\r\nThe proposed depth was 3250 m. The pre-drill classification of the well was\r\nwildcat.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well is Type Well for the Ile and Not\r\nFormation of the Fangst Group.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 6507/11-3 was spudded with the\r\nsemi-submersible installation Treasure Saga on 3 June 1985 and drilled to TD at\r\n3250 m in the Triassic Grey Beds. While drilling the reservoir, mud weight had\r\nto be raised gradually to 1.6 g/cm3 due to high trip gas. Approximately 2 weeks\r\nwere lost due to a work conflict. The well was drilled with spud mud down to\r\n421 m, with gel mud from 421 m to 868 m, with gypsum/polymer mud from 868 m to\r\n2615 m, and with gel mud from 2615 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe average background gas down to the 20"\r\ncasing point was 0.4% to 0.8% with peaks at 505 m (3.43%), 540 m (1.08%), 576 m\r\n(1.76%) and 663 m (1.97%). Methane was the only gas component present. The well\r\nproved mainly claystones down to the Fangst Group. The Cainozoic with a total\r\nthickness of 1771 m overlies a 271 m Cretaceous sequence. Late Jurassic\r\nconsisted of 14.5 m hot shale of the Spekk Formation and 39.5 m of silty\r\nclaystones of the Melke Formation. The Fangst Gr","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"463","properties":{"OBJECTID":463,"wlbNpdidWellbore":471,"wlbName":"7120/5-1","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 7120/5-1 was drilled west of\r\nthe Snøhvit Field on a separate structure, the Alpha structure in the\r\nHammerfest Basin. The main objective of the well was to test possible\r\nhydrocarbon accumulations in the Alpha structure of Middle to Lower Jurassic\r\nage. A secondary objective was to drill into rocks of upper Triassic age at a\r\nprognosed depth of 3047 m.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 7120/5-1 was spudded by Smedvigs\r\nsemi-submersible rig West Vanguard 17 April 1985, and completed 6 June 1985.\r\nThe well was drilled with spud mud down to 885 m and with gypsum/polymer mud\r\nfrom 885 m to TD. Seventy-four meter below the 20" casing shoe, after the\r\nwell had penetrated a fault at 954 m, high background gas with heavy components\r\nwas encountered. The high background gas persisted throughout this section down\r\nto the 13 3/8" casing point at 1975 m. Drilling went on without any\r\nserious problems.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe lithology in the Tertiary and\r\nCretaceous comprises clay with scattered Lime-, Dolomite- and Siltstone layers.\r\nThe Jurassic Stø Formation was encountered at 2285 m represented by clayey\r\nsands, while the clean part of that formation came in at 2341 m. Nordmela\r\nFormation was found at 2427 m, and top of Triassic rocks, Fruholmen Formation,\r\ncame in at 2648 m. Both Stø- and Nordmela Formations were water bearing, but\r\nwith good oil shows. Geochemical analyses of extracts from this interval showed\r\na waxy oil. In a sandy zone between 2405 m to 2420 m high resistivity values\r\nwere encountered, but RFT tests and pressure measurements gave negative\r\nresults. Good source potentials were found in mudstones below ca 1900 m. Shales\r\nfrom 1900 m to 2230 m had TOC in the range 1 % - 3.5 %. A 20 m thick, very\r\norganic rich shale with 6 - 19 % TOC was encountered from 2251 m to 2271 m in\r\nthe Hekkingen Formation. Below this level to TD, frequent claystone interbeds\r\nhad TOC in the range 0.5 % - 5.5 % in cuttings (up to 13.42 % in a swc from\r\n2351.2 m). Th","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"464","properties":{"OBJECTID":464,"wlbNpdidWellbore":472,"wlbName":"25/1-8 S","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe Frigg Field was discovered by well\r\n25/1-1 in 1971 and set in production in May 1977. Well 25/1-8 S was drilled to monitor\r\nchanges in gas/fluid contact, uncover permeability barriers and pressure\r\ngradients in the Frigg Formation, refine the geological model, and provide ties\r\nfor seismic interpretations. Before production started the Frigg Field fluid\r\ncontacts were: OWC = 1955.9 m TVD MSL and GOC = 1948.2 m TVD MSL. Due to the\r\nclose proximity to the Odin pipeline, the well had to be drilled with a slight\r\ndeviation. The well was to be entered several times to monitor further changes\r\nin the gas/water contact as a response to field production.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 25/1-8 S was spudded with\r\nthe semi-submersible installation Byford Dolphin on28 May 1985 and drilled to\r\nTD at 2650 m (2572 m TVD / 2547 m TVD MSL) in the Paleocene Lista Formation. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eTop Frigg Formation came in at 1930.2 m\r\n(1853 m TVD MSL). The formation was gas-bearing with a water saturation of only\r\n6.1% in the gas zone down to the gas/water contact (GWC) at 1901.5 m TVD MSL. A\r\nresidual gas zone with 74.9% water saturation was found from 1901.5 m TVD MSL down\r\nto 1909.3 m TVD MSL. Within this zone, at 1903.5 m TVD MSL was a thin oil layer,\r\nwhich indicated a fingering effect caused by edge water drive. Otherwise the\r\noriginal oil-leg in Frigg had been all swept by water since production start. A\r\nthree phase zone (oil+gas+water) with 51.5% water saturation was seen below the\r\ngas zone from 1909.3 m TVD MSL down to the original GOC at 1948.2 m TVD MSL,\r\nand from 1948.2 TVD MSL down to 1981.1 m TVD MSL there was a zone of residual\r\noil and water with 88.2% water saturation. Below 1981.1 m TVD MSL there was\r\nonly water in the porosity.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=M","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"465","properties":{"OBJECTID":465,"wlbNpdidWellbore":473,"wlbName":"7120/2-1","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 7120/2-1 was drilled on the\r\nLoppa High in the Northern part of the block, a previous unexplored province.\r\nThe primary objective of well 7120/2-1 was to test the reservoir and\r\nhydrocarbon bearing potential of Early-Middle Carboniferous rocks, truncated by\r\na major unconformity predicted at Base Ladinian\u003c/p\u003e\r\n\r\n\u003cp\u003eThe secondary objective was to test the\r\nreservoir (and thereby the seal) potential of Intra Middle Triassic sediments\r\ndeposited above the Base Ladinian unconformity, and to also penetrate a\r\nsufficiently thick interval of the Lower Permo-Carboniferous wedge, which was\r\nprognosed to pinch out above the Early Middle Carboniferous section, in order\r\nto obtain adequate stratigraphic evaluation. It was considered a possibility that\r\nsuch an interval would be of reservoir quality, though probably being better\r\ndeveloped to the east. The well was also expected to fulfil the license\r\ncommitment by drilling into Devonian rocks, or to 4000 m, whichever came first.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was spudded with W.Wilhelmsen\r\nsemi-submersible rig Treasure Scout on 5 May 1985 and drilled through ?Early\r\nCarboniferous sediments to TD at 3502 m in altered dolerites of indeterminate\r\nage. Due to a work conflict, while drilling a pilot hole prior to the 17\r\n1/2" section, drilling was halted for 13 days. The drill string penetrated\r\na pocket of shallow gas between 618 m and 622 m as predicted by shallow seismic\r\nreflectors. The well was drilled with seawater and hi-vis pills down to 1050 m\r\nand with KCl/polymer mud from 1050 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eA major unconformity (613 m) separates\r\nthe Tertiary from the Triassic sediments with missing sediments in the age\r\nrange Late Triassic to Early Paleocene. The Triassic sandstone prognosed to\r\n1850 m was not found. A second stratigraphic break was observed at 1945 m,\r\nwhere Middle Triassic sediments were found resting unconformably on sediments\r\nof Early Permian age (the Base Ladinian Unconformity). A","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"466","properties":{"OBJECTID":466,"wlbNpdidWellbore":474,"wlbName":"6407/7-1 S","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 6407/7-1 S is located ca 30 km west\r\nof the Draugen field on the Njord A-structure in the southern part of the\r\nHalten Terrace. The apex of the A-structure is at about 2600 m MSL. The\r\nstructure has a complex geology with dense faulting. The objective was to test\r\nfor hydrocarbons in the structure, with the Middle and Early Jurassic as the\r\nprimary and secondary targets. In addition, the well should obtain reservoir\r\ndata from the Middle and Early Jurassic reservoir sandstones and establish a\r\nbetter stratigraphical, sedimentological, and structural knowledge of the area.\r\nThe well should penetrate a deep reflector interpreted to be the "Top\r\nMiddle Triassic Evaporite reflector". The prognosed total depth was 4025\r\nm.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 6407/7 1 S was spudded with\r\nthe semi-submersible installation Polar Pioneer 19 October 1985 and was drilled\r\nto TD at 3950 m in Triassic rocks. Ca 30 days (17%) of the rig time was down\r\ntime. Major causes for this were sub sea problems with orienting the temporary\r\nguide base, bad weather, and fishing for various objects and stuck tools. In\r\naddition the section from ca 746 to 1177 m required wiper trips and a lot of\r\nreaming to clean the hole. This added several days to the drilling time. The\r\nwell was vertical down to 1177 m, it built deviation angle up to maximum 9.8\r\ndeg at 1460 m, and had a deviation between 9.8 and 3.0 deg from there to TD. The\r\nwell was drilled with spud mud down to 1172 m, with KCl/polymer mud from 1172 m\r\nto 2710 m, with gel/polymer mud from 2710 m to 3601 m, and with\r\ngel/lignosulphonate mud from 3610 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe top of the reservoir came in at 2759\r\nm, 70.5 m higher than prognosed. Oil was discovered in three separate reservoir\r\nunits. The upper reservoir (2759 - 2783.5 m) consisted of sandstones belonging\r\nto the Fangst Group and Ror Formation. Relative pressure in this unit was 1.35\r\ng/cc. The main reservoir (2839 -2988 m) consisted of sandstones be","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"467","properties":{"OBJECTID":467,"wlbNpdidWellbore":475,"wlbName":"6506/12-4","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 6506/12-4 was drilled on the\r\nAlpha north segment in the northern part of the Smørbukk field, Haltenbanken.\r\nThe primary objective was to test the hydrocarbon bearing potential of Middle\r\nJurassic Sandstones.\u003c/p\u003e\r\n\r\n\u003cp\u003eSecondary objectives were to test Early\r\nJurassic sandstones within the coal beds, and possible sand development within\r\nthe Cretaceous. The prognosed depth was 4457 m or rocks of Triassic age to\r\nsatisfy the licence commitment.\u003c/p\u003e\r\n\r\n\u003cp\u003e \u003c/p\u003e\r\n\r\n\u003cp\u003eThe well is the typewell for the Melke,\r\nSpringar, and Nise Formations, and reference well for the Viking and Cromer\r\nKnoll Groups and the Lange, Lysing, and Kvitnos Formations (NPD Bulletin no 4)\u003c/p\u003e\r\n\r\n\u003cp\u003e \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 6506/12-4 was spudded with\r\nDyvi Offshore installation Dyvi Stena 24 March 1985 and drilled to TD at 4457 m\r\nin the Early Jurassic Åre Formation. The well was drilled with seawater and\r\nhi-vis pills down to 680 m where a shallow gas pocket caused the well to flow.\r\nThe gas was led through the diverter system and mud weight was increased. This\r\nled to lost circulation, but control was gradually regained after pumping LCM\r\npills. A cement plug was set between 600 m and 680 m. The 20" casing was\r\nset shallow at 622 m and drilling commenced with a Gypsum / Lignosulphonate mud\r\nsystem to the 8 1/2" section at 3936 m from where a weighted\r\nlignosulphonate mud system was used the rest of he well bore down to TD. During\r\ncoring operation, at 3978 m, a water kick was experienced, but was brought\r\nunder control. During cleanup at TD the drill string got stuck. While\r\nattempting to work this free, the string fell of the hook. Three weeks were\r\nspent on fishing for the string without complete success. The top of the fish\r\nis left at 3910 m.\u003c/p\u003e\r\n\r\n\u003cp\u003eAbout ten m sandstone was encountered in\r\ntop Lysing Formation (Late Cenomanian ? Turonian). The sandstone was cored and\r\nit contained hydrocarbons but none were produced during DST. The G","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"468","properties":{"OBJECTID":468,"wlbNpdidWellbore":476,"wlbName":"34/10-23","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 34/10-23 was drilled on the Gullfaks\r\nGamma structure, south-southeast of the Gullfaks Sør Field in the Northern\r\nNorth Sea. The objectives were to prove a significant hydrocarbon accumulation,\r\nwith the Brent Group as the primary target and the Early Jurassic as secondary target.\r\nThe first well on the structure, well 34/10-20, had the same targets as\r\n34/10-23, but was terminated in the Early Cretaceous due to technical problems.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 34/10-23 was spudded with\r\nthe semi-submersible installation Dyvi Delta on 6 May 1985 and drilled to TD at\r\n4764 m into Sinemurian /possibly Rhaetian age sediments of the Statfjord\r\nFormation. The well took 28 days more than prognosed to drill. The main part of\r\nthe extra time came in the 8 1/2" section, where among many other things,\r\nthe BOP stack was pulled for inspection and repairs. A flow occurred at 4080 m just\r\nabove top Brent Group, and approximately three days were used to bring the well\r\nunder control. At 4409 m (4406.5 m TVD RKB) the deviation exceeded 5 deg. The\r\nlast survey, at 4514 m (4510.8 m TVD RKB) m showed 9.1 deg deviation. If this\r\ndeviation is extrapolated the vertical depth at TD is 4756.2, ca 8 m short of\r\nmeasured depth. The well was drilled with seawater and hi-vis pills down to\r\n1252 m, with gypsum/lignosulphonate mud from 1252 to 3118 m, and with\r\ngypsum/lignosulphonate/lignite mud from 3118 m to 4525 m. At 4509 m the pipe\r\nstuck, and imco-spot/pipelax pills with 3% diesel were placed to free it. The\r\nfinal section from 4525 m to TD was drilled with a\r\ngel/lignosulphonate/lignite/Anco Resin mud system. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe pore pressure increased through the\r\nentire Cretaceous section and reached a maximum of 1.96 g/cc at the top of the\r\nBrent Group. Gas bearin","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"469","properties":{"OBJECTID":469,"wlbNpdidWellbore":477,"wlbName":"25/2-9","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 25/2-9 was\r\ndesigned to drill an assumed top in the eastern part of the Frigg East Beta\r\nstructure, one of the Frigg Satellites, discovered by well 25/2-1 in 1973. The\r\nmain objects of this well was to reveal petrophysical characteristics in an\r\narea where development wells could be located, to appraise the gas column\r\nheight and gas in place, to get static formation pressure in order to estimate\r\ncommunication with the main Frigg field, and to obtain cores from the upper\r\npart of the Frigg Formation and the Balder formation for static and dynamic\r\npetrophysical measurements. Prognosed depth of the Frigg Formation was 1922 m,\r\nand planned TD was 2450 m.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eAppraisal well\r\n25/2-9 was spudded with Golar Nor Offshore A/S semi-submersibel rig Nortrym on\r\n14 June 1985 and completed 24 July 1985 at a depth of 2297 m in the Paleocene\r\nBalder Formation. At 2297 m 800 l/min of mud was lost due to a leakage between\r\n13 3/4" casing and 20" casing. The 9 5/8" casing was set to 888\r\nm and the well was gradually brought under control. During this operation a\r\npart of the under-reamer was lost into the hole, and fishing went on for two\r\ndays.\u003c/p\u003e\r\n\r\n\u003cp\u003eTop Frigg came in at\r\n1935 m with hydrocarbons from 1935.9 m. Gas/oil contact was encountered at 1960\r\nm, and an oil/water contact at 1972 m with brown oil stain on cuttings down to\r\n2008 m. A total of 12 cores were cut with a total length of 214.25 m with 86%\r\nrecovery. Ten cores were cut from 1939 m to 2145 m in the upper Frigg\r\nFormation, across the hydrocarbon bearing zone and all fluid contacts and two\r\ncores were cut from 2220 m to 2256 m in the tuffaceous Balder Formation. The\r\ncores consisted mainly of sands, more or less consolidated. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was plugged\r\nand abandoned as an oil and gas discovery.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test\r\nwas performed\u003c/p\u003e\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"470","properties":{"OBJECTID":470,"wlbNpdidWellbore":478,"wlbName":"30/9-5 S","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 30/9-5 S was drilled on the\r\n"J" prospect close to the western margin of the Horda Platform. The\r\nstructure is bounded by Jurassic strata dipping down into the north, east and south\r\nand by the main Horda Platform fault to the west. The primary objective was to\r\nprove hydrocarbon accumulation in the Etive Formation of the Brent Group.\r\nSecondary objectives were possible hydrocarbons in sandstones if present in the\r\nHeather-Drake- and Cook Formations.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 30/9-5 S was spudded with\r\nthe semi-submersible installation Treasure Seeker on 27 May 1985 and drilled to\r\nTD at 2980 m (2963 m TVD) in the Triassic Hegre Group. Due to shallow gas\r\nindications on the site survey seismic the well location was moved approximately\r\n150 m. The well was then deviated from a kick off point at 1000 m to reach the\r\nplanned target. No significant problem was encountered in the operations. The\r\nwell was drilled with seawater and gel down to 910 m, with KCl/polymer mud from\r\n910 m to 1935 m, and with NaCl/polymer mud from 1935 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well encountered a gas bearing Cook\r\nFormation and minor amounts of gas in the Brent Group. No additional\r\nhydrocarbon bearing reservoirs were encountered by the well. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe Brent Group (2236-2253 m, 2222-2239 m\r\nTVD) was found severely eroded in the well with poorly developed sands. The net\r\nsand distribution is limited to a thin layer at the top of the formation. The\r\nrest of the formation appears to be very silty. The gross thickness is 17 m\r\nwith a net pay of only 0.5 m. The average porosity is 20.2% and the water\r\nsaturation 58.2%. The Cook Formation (2447-2466 m, 2433-2452 m TVD) has\r\nmoderately good reservoir qualities in the upper p","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"471","properties":{"OBJECTID":471,"wlbNpdidWellbore":479,"wlbName":"7121/5-1","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 7121/5-1 is located on the\r\neastern part of the Snøhvit Field. It was drilled about 75 m down flank on the\r\nAlpha-structure in the block. The Snøhvit structure consists of an east-west\r\nrunning horst and a rotated normal faulted block. The main objective in the\r\nwell was to test possible reservoir rocks of Jurassic/Triassic age as seen in\r\nneighbouring wells. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 7121/5-1 was spudded with the\r\nsemi-submersible installation West Vanguard on 7 June 1985 and drilled to TD at\r\n3200 m. The rig was shut down from 16 June to 30 June due to a strike.\r\nOtherwise drilling proceeded without significant problems. The well was drilled\r\nwith spud mud down to 865 m, with a gypsum/polymer mud from 865 m to 1925 m, and\r\nwith polymer mud from 1925 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eTop reservoir came in at 2369 m with\r\nhydrocarbons. From RFT pressure measurements the gas/oil contact was found at\r\n2427.5 m and the oil/water contact at 2442 m. Logs displayed sands with\r\npossible hydrocarbons in Triassic sandstones, but increasing shale down hole\r\nreduced porosity/permeability and DST test confirmed a tight formation.\r\nGeochemical analyses showed immature rocks until 2250 m and marginal to\r\nsignificant maturity in Triassic/Jurassic rocks respectively. Nine cores were\r\ncut in the interval 2365 m to 2523 m in the Stø, Nordmela and Tubåen Formations.\r\nOne core was cut from 3088 m to 3109 m in the Triassic Snadd Formation. Four\r\nRFT segregated samples were taken in the upper part of the Stø and Nordmela Formations\r\nfrom 2370 m to 2434 m, one in the Tubåen Formation at 2507 m, and one at 2802.7\r\nm in the Snadd Formation. A small amount of condensate in the sample from 2370\r\nm was the only reported liquid hydrocarbons from the RFT samples. Otherwise gas\r\nwas recovered in the samples from 2424 m and 2370 m, while the sample from 2507\r\nrecovered mainly water/mud filtrate and minor gas. The sample from 2802.7 m\r\ncontained only minor amounts of mud filtrate and no","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"472","properties":{"OBJECTID":472,"wlbNpdidWellbore":480,"wlbName":"6407/9-4","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eAppraisal well 6407/9-4 is the fourth\r\nwell on the Draugen Field. The main objective was the Late Jurassic Rogn\r\nFormation. Wells 6407/9-1, 6407/9-2 and 6407/9-3 had previously encountered under-saturated\r\n40 deg API oil in sandstones of the Late Jurassic Rogn Formation. Net oil sand\r\nthicknesses in the three previous wells were 39, 12 and 34 m, respectively.\r\nPrecise definition of the OWC in well 6407/9-1 was precluded by poor quality\r\nlithology at the base of sequence. A clearly defined oil-water contact at\r\n1638.5 m MSL was however encountered in well 6407/9-2. The purpose of this\r\nfourth well was to evaluate the reservoir quality and sand development on the north-west\r\nflank of the accumulation, and to evaluate the oil deliverability and water\r\ninjection potential of the reservoir sands.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 6407/9-4 was spudded with the semi-submersible\r\ninstallation West Venture on 4 July 1985 and drilled to TD at 1820 m in the\r\nEarly Jurassic Tilje Formation. No significant problems were encountered while\r\ndrilling the well. The well was drilled with seawater and bentonite down to 820\r\nm, with KCl/polymer mud from 820 m to 1635 m, and with chalk mud from 1635 m to\r\nTD.\u003c/p\u003e\r\n\r\n\u003cp\u003eLight oil with low gas content was\r\ndiscovered in the Garn Formation, as the Rogn Formation proved to be only 2 m\r\nthick. The oil/water contact was found at 1672 m (1639 m MSL), the same contact\r\nthat had been established in previous wells on the Draugen Field. This\r\nindicated communication in the Rogn and Garn Formations between the wells\r\ndrilled so far on Draugen. No oil shows were recorded above the reservoir.\r\nBelow OWC oil shows continued down to 1681 m, otherwise no further oil shows\r\nwere observed. \u003c/p\u003e\r\n\r\n\u003cp\u003eFive cores were cut from 1666 m to 1711.5\r\nm in the Fangst Group. An RFT segregated fluid sample was taken at 1664.5 m in\r\nthe upper Garn Formation. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 10\r\nSeptember 1985 as an oil appraisal well.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003c","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"473","properties":{"OBJECTID":473,"wlbNpdidWellbore":482,"wlbName":"6507/7-3","wlbHistory":"\r\n\r\n\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 6507/7-3 was drilled in\r\nthe northern part of the Haltenbanken area, some 190 km west of the Norwegian\r\ncoast. It was drilled to evaluate the "B" prospect in the intensely\r\nfaulted zone that lies at the intersection of the Nordland Ridge in the\r\nnortheast and the Halten Terrace in the south. The prospect was in a southward\r\nplunging horst block formed by a Late Jurassic tensional fault system. The well\r\nwas drilled down dip from the 6507/7-2 discovery well. It was designed to test\r\nthe Middle Jurassic sands to determine whether an oil leg was present.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 6507/7-3 was spudded with the\r\nsemi-submersible installation Nortrym on 29 July 1985 and drilled to TD at 2850\r\nm in Early Jurassic sediments of the Åre Formation. Few problems were\r\nexperienced during operations on 6507/7-3, those that did occur were\r\npredominantly related to gumbo and tight hole conditions. There were no serious\r\naccidents or problems during the operation. A total of 54 days was spent on\r\ndrilling, logging, testing, and completion. The well was drilled with sea water\r\nand gel sweeps down to 1030 m, and with gypsum/polymer mud from 1030 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe Late Cretaceous (Santonian) was found\r\ndirectly overlying the Middle Jurassic (Callovian) Fangst Group as anticipated.\r\nNo hydrocarbon fluorescence or staining was observed until the top of the Fangst\r\nGroup at 2367.5 m. The Fangst and Båt Group was found oil bearing down to claystones\r\nbelonging to the Ror Formation at 2540 m. Patchy fluorescence and a slight\r\nhydrocarbon odour persisted down to 2448 m. Using gradients established from\r\nelectric logs, excellent RFT pressure data, and fluid analysis, the true oil/water\r\ncontact was however indicated to be at 2491 m. No hydrocarbon","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"474","properties":{"OBJECTID":474,"wlbNpdidWellbore":483,"wlbName":"34/10-24","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 34/10-24 was drilled to test\r\npossible shallow gas accumulation in sandstones at the location for the\r\nGullfaks A platform. The targets were several sand layers of Pliocene age between\r\n313 m and 600 m. Gas had been indicated on seismic anomalies and logs from\r\nother wells in the same field.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 34/10-22 was spudded with the\r\nsemi-submersible installation Deepsea Bergen on 28 June 1985 and drilled to TD\r\nat 600 m in Pliocene sediments in the Nordland Group. No significant problem\r\nwas encountered in the operations. The well was drilled with water based mud.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eTop Pliocene was encountered at 285 m. The\r\nwell encountered sand layers at 334.5 to 337.5 m, 346 to 347 m, and at 436 to\r\n441 m. The sand at 334.5 to 337.5 m was gas bearing. According to previous log\r\ncorrelations, the well should have run into rocks of Miocene age. But\r\nbiostratigraphical investigations proved only fauna of Pleistocene and\r\nPliocene, age.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo cores were cut and no wire line fluid\r\nsamples were taken. Cuttings samples were collected every 5 m from 230 m to TD.\r\nA full set of conventional logs where run. Maximum bottom hole temperature on\r\nwire line, measured 4 hours after circulation was 29.2 deg C.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was permanently abandoned on 5 August\r\n1985.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eTesting\u003c/span\u003e\u003c/b\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eOne DST test was performed in the\r\ninterval 334.5 to 336 m in order to bleed of the gas down to less than\r\nhydrostatic pressure. The sand was acid treated and gravel packed and over a ca\r\none week period the well flowed 56 -71 Sm3 gas/day through two paral","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"475","properties":{"OBJECTID":475,"wlbNpdidWellbore":484,"wlbName":"7120/1-1","wlbHistory":"\r\n\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 7120/1-1 was drilled on the Alpha\r\nstructure in the north of block 7120/1. The primary objective of the well was\r\nto test Palaeozoic carbonates and elastics in a partly fault-bounded/truncated\r\ndip closure on the western flank of the Loppa High. Potential Early Triassic\r\nsandstones in a low relief dip closure were a secondary objective.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 7120/1-1 was spudded on 16 August\r\nwith the semi-submersible installation "Borgny Dolphin" and drilled\r\nto 2569 m where it was suspended on 15 November due to NPD drilling regulations\r\nduring winter season. On 2 December permission was granted to continue\r\noperations and drilling continued to 2610 m. On 26 December the well was again\r\nsuspended at the request of the Norwegian Petroleum Directorate because of\r\nsafety considerations in adverse weather conditions. The well was re-entered on\r\n13 March 1986 and drilled to a TD of 4003 m in basement rocks. The well was\r\ndrilled with seawater and bentonite hi-vis pills down to 485 m. From there to TD\r\ngypsum/polymer mud was used with various "Lost Circulation Material"\r\npills to cure mud losses. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well encountered weak hydrocarbon\r\nshows from 800 m down to 2200 m\u00A0 and oil shows in Late Permian carbonates\r\n(Tempelfjorden Group, Ørret Formation).\u00A0 No intervals of significant reservoir\r\npotential were recognized from logs or described from cuttings in the Tertiary\r\nor Triassic sections. Below this sequence, three main Permian carbonate units\r\nwere identified from logs and cuttings description. A porosity range of 5-10%\r\nfor the limestone sequence between 2415 and 2461 m has been derived from log\r\nevaluation. In the basal part of this interval, a black shale was detected with\r\na gas peak of 13% total gas. The lower limestone inte","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"476","properties":{"OBJECTID":476,"wlbNpdidWellbore":485,"wlbName":"6507/12-3","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 6507/12-3 was drilled east\r\nof and near to the Midgard field on Haltenbanken. The main objective was to\r\ntest the W-1 prospect located on the western margin of the Trøndelag Platform,\r\non the eastern edge of the Ellingråsa Graben. The structure was seen as a domed\r\nN-S striking horst restricted by the main platform fault to the west and a\r\nrelated antithetic fault to the east with throws of approximately 350 m and 100\r\nm, respectively. Primary target was the Middle Jurassic sandstones of the\r\nFangst Group. A secondary target was the Lower Jurassic sandstones of the Tilje\r\nFormation, and to penetrate the coal horizon in the Åre Formation. Proposed TD\r\nwas at 2700 m.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 6507/12-3 was spudded with Wi1h. Wi1helmsen\r\nsemi-submersible installation Treasure Saga on 16 August 1985 and drilled to TD\r\nat 2600 m in the Early Jurassic Åre Formation. The well was drilled with spud\r\nmud down to 380 m, with gel mud from 380 m to 920 m, with Gypsum / Polymer mud\r\nfrom 920 m to 1949 m, and with a gel mud again from 1949 m to TD. A gas flow\r\noccurred between the 20" and 30" casing. The casing was perforated at\r\n705 m and cement successfully squeezed. Gas flow continued to be a problem and\r\nthe 13 3/8" casing was also perforated and cement squeeze was performed in\r\nboth the lower and upper perforations.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe Quaternary/Tertiary Sequence was 1596\r\nm thick and consisted predominantly of marine claystones. Cretaceous was\r\nrepresented by a 75 m sequence of Springar Formation. Two metre of Spekk\r\nFormation was encountered at 1937 m, followed by 33 m of Melke Formation. The\r\nFangst Group was penetrated at 1974 m, 20 m above the prognosed depth. MWD\r\ndisplayed fall in resistivity and the formation was considered dry. All\r\nJurassic sandstone sequences were water bearing. A number of gas peaks were\r\nrecorded from 474 m to 804 m, but there were no oil shows observed in the well.\u003c/p\u003e\r\n\r\n\u003cp\u003eTwo cores were attempted in the in","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"477","properties":{"OBJECTID":477,"wlbNpdidWellbore":486,"wlbName":"6406/6-1","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 6406/6-1 was drilled on the Eta\r\nstructure in the northwest corner of a block located just south of the Trestakk\r\nand Smørbukk discoveries. The main objective was hydrocarbon accumulations in\r\nMiddle Jurassic sandstones. The second objective was Early Jurassic sandstone.\r\nTotal depth was to be in rocks of Triassic age in order to satisfy the licence\r\ncommitment.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 6406/6-1 was spudded with the\r\nsemi-submersible installation Dyvi Stena on 15 August 1985 and drilled to TD at\r\n4715 m in the Early Jurassic Tilje Formation. While setting the 9 5/8"\r\ncasing several problems occurred, starting with difficulties in setting and\r\ntesting the seal assembly, followed by leakage of the failsafe valves and\r\nfailure of the BOP acoustic system. This resulted in a total loss of 28 days.\r\nThe drilling proceeded to 4715 m, and the 7 m liner was run to 4696 m. Further\r\nproblems, loss of several pieces of equipment in the hole and evaluation of the\r\nlogs, resulted in the NPD approving the operators request to plug the hole 460\r\nmeter short of the prognosed depth. The well was drilled with seawater and\r\nhi-vis pills down to 333 m, with gel/seawater from 333 m to 965 m, with\r\ngypsum/lignosulphonate mud from 965 m to 4165 m, and with lignite/lignosulphonate\r\nfrom 4165 m to TD. \u003c/p\u003e\r\n\r\n\u003cp\u003eTraces of hydrocarbons were indicated at\r\nca 3900 m in thin beds of sand stone of Early Cretaceous age. Sandstones were\r\nencountered in the Early - Middle Jurassic (Garn Ile and Tofte Formations). No\r\nhydrocarbons were observed in the Garn Formation. Weak oil shows were seen in\r\nthe Ile and Tofte sandstones.\u003c/p\u003e\r\n\r\n\u003cp\u003eOnly one core was cut in the top of the\r\nGarn (former Tomma I) Formation. RFT sampling was attempted but all samples\r\nfailed to recover formation fluid either due to plugging or to seal failure.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 30\r\nDecember 1985 as a dry well with shows.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was perfo","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"478","properties":{"OBJECTID":478,"wlbNpdidWellbore":487,"wlbName":"30/6-17","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 30/6-17 was drilled on the Alpha\r\nstructure on the western side of the Oseberg Field in the northern North Sea.\r\nThe structure is a tilted and rotated fault block with a Jurassic sequence\r\ndipping towards the east. The main objective was to prove hydrocarbons in the\r\nStatfjord Formation. Prognosed depth was 200 m into the Statfjord Formation\r\nwith TD at ca 2682 m.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 30/6-17 was spudded with the\r\nsemi-submersible installation Vildkat Explorer on 12 August 1985 and drilled to\r\nTD at 615 m in Pliocene sediments of the Nordland Group. The well was drilled\r\nto TD in the 26" section and the 20" casing was set at 601 m. When\r\npreparing to run the BOP the travelling block hit the crown block. Because of\r\nserious damage to equipment involved the decision was made to temporary abandon\r\nthe well. The well was drilled with spud mud.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo cores were cut and no wire line fluid\r\nsamples were taken.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was permanently abandoned on 24\r\nAugust 1985 as a dry well.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eTesting\u003c/span\u003e\u003c/b\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo drill stem test was performed.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"479","properties":{"OBJECTID":479,"wlbNpdidWellbore":488,"wlbName":"30/6-18","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 30/6-18 was\r\ndrilled on the Kappa structure, which is located in the south-western corner of\r\nthe block. Kappa is an elongated down faulted block bounded by north south\r\ntrending major faults to the east and the west. The structure is an easterly\r\ntilted fault block where the Base Cretaceous truncates both the Brent Group and\r\nthe Statfjord Formation. The main objective of the well was to prove\r\nhydrocarbons in the Statfjord Formation by drilling on a location that leaves a\r\nminimum of possible reserves up dip of the well. Secondary objectives were to\r\nimprove stratigraphical and structural knowledge of the area and to acquire\r\ninput data for further exploration activity in blocks 30/6 and 30/9.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 30/6-18\r\nwas spudded with the semi-submersible installation Byford Dolphin 1 August 1985\r\nand drilled to TD at 3690 m in Late Triassic rocks. Drilling proceeded without\r\nany significant problems. The well was drilled with spud mud down to 658 m and\r\nwith a KCl polymer mud from 658 m to TD. The Statfjord Formation came in 120 m\r\nhigher than prognosed. The logs show that the Statfjord Formation contains 16 m\r\nof gas and 44 m of oil. Oi1/water contact was defined at 3181 m. The reservoir\r\nquality seems to be good. There is a separate column of 19 m oil further down\r\nin the Statfjord Formation. A thick shale sequence from 3287 to 3305 m\r\nseparates the upper reservoir unit from the lower. The lower oil column is\r\nprobably restricted to only one layer of sand with a gas cap on top. Eight cores\r\nwere cut in the Statfjord Formation in the interval 3126 - 3215 m. Three sets\r\nof segregated RFT samples were retrieved from 3165 m, 3125.5 m, and 3312.8 m in\r\nthe Statfjord Formation. The well was plugged and abandoned on 23 November 1985\r\nas an oil and gas discovery.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting \u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThree drill stem\r\ntests were performed in this well. The intervals were 3306 m - 3323 m, 3198 m -\r\n3210 m and 3164 m & 3173.2 m.\u003c/p\u003e\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"480","properties":{"OBJECTID":480,"wlbNpdidWellbore":489,"wlbName":"30/6-19","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 30/6-19 was drilled on the Beta\r\nSaddle prospect between the Veslefrikk field and the 30/6-5 Oseberg East (Beta\r\nSouth) discovery. The objectives of the well were to prove hydrocarbons in the\r\nBrent Group, the Cook Formation, and the Statfjord Group. Planned TD was ca\r\n3400 m or ca 100 m into the Statfjord Formation.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 30/6-19 was spudded with the\r\nsemi-submersible installation Polar Pioneer on 9 April 1986 and drilled to TD\r\nat 3301 m in the Early Jurassic Statfjord Group, Eirikson Formation. Drilling\r\nproceeded without significant problems down to 1589 m where the string got\r\nstuck and the well was sidetracked at 1179 m. At 3117 m the string got stuck\r\nand a cement plug was set at 2847 m. The well was sidetracked again at 2822 m\r\nand drilled to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe Brent Group (2857 - 2989 m) contained\r\noil down to the OWC at 2956.5 m (Free water level from RFT). Net pay in the oil\r\nzone is 58.1 m with an average porosity of 18.8% and an average water saturation\r\nof 48.3%. No additional hydrocarbon reservoirs were encountered by the well and\r\nonly occasional weak shows were seen on sandstone stringers in the Drake\r\nFormation and single grains in the Statfjord Group. RFT pressures showed the\r\nCook Formation to be overpressured and the Statfjord Group to be underpressured\r\nrelative to the Brent Group. This assumes same water density as in the Brent\r\nGroup water zone. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eFour conventional cores were cut in the\r\nBrent reservoir from 2858 - 2970 m. Core depths are ca 1.5 m shallower than logger's\r\ndepth. RFT pressure recordings were performed throughout the Brent Group and in\r\nthe Cook and Statfjord Formations. Segregated RFT samples were taken in the final\r\nsidetrack in the Ness Fo","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"481","properties":{"OBJECTID":481,"wlbNpdidWellbore":490,"wlbName":"6407/4-1","wlbHistory":"\r\n\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 6407/4-1 was drilled on a\r\nstructure in the Gimsan Basin on the Halten Terrace, in the central part of the\r\nblock. The structure is an isolated domelike structure, all inside the block\r\nborders. Well 6407/4-1 is placed a little down flank on the biggest segment in\r\nthe southeast part. The main objective was hydrocarbon accumulations in the\r\nMiddle Jurassic, Garn Formation. The second objective was Middle Jurassic,\r\nTilje Formation.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003e6407/4-1 was spudded with the\r\nsemi-submersible rig Ross Isle on 20 July 1985 and drilled to TD at 4835 m in\r\nlate Triassic sediments of the Åre Formation. The well was drilled with\r\nseawater and gel down to 849 m, with gypsum/polymer mud fro 849 m to 2121 m,\r\nwith gypsum/polymer/lignosulphonate mud from 2121 m to 3817 m, and with\r\ngel/lignosulphonate/lignite mud from 3817 m to TD. Drilling the well proceeded\r\nwithout significant problems. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eOil shows were recorded in sandstone in\r\nthe interval 2467 m to 2720 m in Campanian-Santonian-Coniacian age sediments of\r\nthe Shetland Group. Hydrocarbon bearing Middle Jurassic sandstones were\r\nencountered at 3890 m KB. Good and strong continuous shows were recorded\r\nthroughout the Spekk and Melke Formations and the Fangst Group. Geochemical\r\nanalyses recorded continuous shows in the Tilje Formation (down to ca 4330 m),\r\nsome shows in sandstones of the Åre Formation, and they confined the oil-water\r\ncontact in the Garn Formation to between 3952.8 m and 3960.0 m. Above ca 3780\r\nmetres the shows involve a light to medium gravity oil, whilst below this depth\r\nthe oils are waxier and of medium gravity. Top reservoir, in Garn Formation,\r\ncame in at 3889.5 m, 28 m higher than prognosed. Gas was produced from the\r\nreservoir, but reservoir qualities we","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"482","properties":{"OBJECTID":482,"wlbNpdidWellbore":491,"wlbName":"35/3-3","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 35/3-3 was drilled in the\r\nNorwegian sector of the North Sea approximately 50 km west of Måløy, Norway.\r\nThe primary target was to test the possible extension of Lower Cretaceous\r\nsandstones to the east of those encountered in wells 35/3-1 and 35/3-2. A\r\nstratigraphic trap was thought to exist in these sandstones. A secondary target\r\nwas possible sandstones of Early Jurassic age with a possible pinch-out trap.\u00A0 \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 35/3-3 was spudded with the semi-submersible\r\ninstallation Byford Dolphin on 30 October 1980. It was drilled and logged to\r\n900 m, then junked because of technical problems running the 20" casing.\r\nThe rig was moved about 20 meters, and the well was respudded on 30 November 30\r\n1980 as 35/3-4.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was performed\u003c/p\u003e\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"483","properties":{"OBJECTID":483,"wlbNpdidWellbore":492,"wlbName":"6407/9-5","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 6407/9-5 was the fifth well drilled on\r\nthe Draugen Field in the southern Haltenbanken area. Wells 6407/9-1, 6407/9-2\r\nand 6407/9-3 delineated an areally extensive oil accumulation in relatively\r\nthin Late Jurassic Rogn Formation sandstone. Net oil sand thicknesses in these\r\nwells were 39, 12 and 34 m respectively. The oil gravity was 40 deg API. Well\r\n6407/9-4, located on the west flank of the northern accumulation, confirmed\r\npinch out of the Rogn Formation and encountered similar oil in the underlying Garn\r\nformation. The initial conditions of pressure and oil water contact in this\r\nwell (1638.5 m MSL were similar to those in the Rogn Formation accumulation. The\r\nobjectives of well 6407/9-5 were to delineate top structure and rock qualities\r\nin the southern culmination. Prognosed TD was 1805 m in rocks of Triassic age,\r\nor a maximum depth of 4000 m.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eAppraisal well 6407/9-5 was spudded with\r\nthe semi-submersible installation West Venture on 12 September 1985 and drilled\r\nto TD at 1820 m in the Early Jurassic Not Formation. Drilling proceeded without\r\nserious problems, except for the sections trough glacial deposits were huge\r\nboulders caused minor problems. The well was drilled vertical. Deepest reported\r\ndeviation survey was at 1675 m (1675 m TVD RKB). To this depth maximum\r\ndeviation from vertical was 0.66 deg. The well was drilled with seawater and\r\nbentonite down to 811 m, with KCl/polymer mud from 811 m to 1625 m, and with\r\nchalk mud from 1625 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe Rogn Formation was encountered at\r\n1654 m, 15 m deeper than prognosed. Light oil was discovered, as known from the\r\nother wells in the Draugen field. The oi1/water contact was found at 1671 m\r\n(1639 m MSL), the same contact as in the other wells drilled on the Draugen Field.\r\nAverage reservoir quality over this 17 m interval was good, with a calculated\r\nhydrocarbon saturation of 76% and a porosity of 27%. Core permeabilities from\r\nthe oil interval typically r","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"484","properties":{"OBJECTID":484,"wlbNpdidWellbore":493,"wlbName":"31/6-8 R","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eAppraisal well 31/6-8 R is a re-entry of\r\nwell 31/6-8 in the south-west corner of the Troll East gas province. The\r\nobjective of the re-entry was an elaborate testing program to obtain a number\r\nof reservoir engineering parameters.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 31/6-8 re-entered (31/6-8 R) on 22\r\nJuly 1985 with the semi-submersible installation Treasure Seeker. The well was\r\ntested without significant technical problems. Operations took 63 days. After\r\ntesting the well was plugged and permanently abandoned on 22 September 1985 as\r\na gas and oil appraisal.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eVarious tests were performed, including a\r\nproduction test, a sand production test, and fracture testing. Test 1 was a\r\nproduction test from the interval 1537.6 m to 1557.6 m as a high-rate test on a\r\nspecial production string. The test produced through gravel pack at maximum\r\n3900000 Sm3 gas /day on a double 2" choke, which was considered a world\r\nrecord for an offshore well. The liquid production at this rate was ca 105 Sm3,\r\ngiving a gas/liquid rate of ca 137000 Sm3/Sm3. The maximum temperature during\r\nthis test, from a gauge at 1528 m, was 68.5 deg. C. \u003c/p\u003e\r\n\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"485","properties":{"OBJECTID":485,"wlbNpdidWellbore":494,"wlbName":"34/10-16 R","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 34/10-16 R is a re-entry of well\r\n34/10-16, which found oil in the Brent Group in the Gullfaks Sør structure, 8\r\nkm south of the Gullfaks Field. The objective of the re-entry was testing and\r\npermanent abandonment.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 34/10-16 was re-entered\r\n(34/10-16 R) on 31 August with the semi-submersible installation Ross Isle. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was tested.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was permanently abandoned on 27\r\nSeptember 1983 as an oil and gas appraisal well.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eTesting\u003c/span\u003e\u003c/b\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eTwo drill stem tests were performed in\r\nthe Brent Group.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eDST1 perforated the interval 3397 to 3407\r\nm and produced 960 Sm3 oil and 182 000 Sm3 gas /day through a 48/64" choke.\r\nThe GOR was 191 Sm3/Sm3, the oil density was 0.86 g/cm3, and the gas gravity\r\nwas 0.67 (air = 1). Maximum temperature recorded down hole was 129 deg C.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eDST2 perforated the interval 3177 to 3187\r\nm and produced 370 Sm3 condensate and 1 650 000 Sm3 gas /day through a\r\n80/64" choke. The GOR was 4118 Sm3/Sm3, the oil density was 0.79 g/cm3,\r\nand the gas gravity was 0.66 (air = 1). Maximum temperature recorded down hole\r\nwas 118 deg C.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"486","properties":{"OBJECTID":486,"wlbNpdidWellbore":495,"wlbName":"34/10-9 R","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 34/10-9 R is a re-entry of well\r\n34/10-9 on the central part of the Gullfaks Field. Well 34/10-9 drilled to 2200\r\nm in the Early Jurassic Burton Formation and proved oil in the Brent Group and\r\nCook Formation. The objective of the re-entry was to drill further to the\r\nStatfjord Formation and to conduct drill stem tests in the Brent Group and Cook\r\nFormation.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 34/10-9 was re-entered\r\nwith the semi-submersible installation Deepsea Saga on 29 May1980 and drilled from\r\n2200 m to final TD at 2421 m in the Nansen Member of the Early Jurassic Statfjord\r\nFormation. Drilling and testing were carried out without any specific problems.\r\nThe well was drilled with a gel/lignosulphonate mud system from 2200 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe Statfjord Formation proved to be\r\nwater bearing.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eTwo cores were cut from 2400 m to 2405.5\r\nm in the Nansen Member of the Statfjord Formation with 74% total recovery. No\r\nwire line fluid samples were taken.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was permanently abandoned 3 July\r\n1980 as an oil appraisal well.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eTesting\u003c/span\u003e\u003c/b\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThree drill stem tests were performed in\r\nthe re-entry. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eDST 1 tested the interval 2103 to 2109 m\r\nin the Cook Formation. The well produced 34.2 API oil at unstable conditions.\r\nThe average flow rate on a 20/64" choke was 42 Sm3/day with a GOR of 69\r\nSm3/Sm3 and traces of water. The maximum temperature recorded down hole at the\r\ngauge was 84.4 deg C.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eDST 2 tested the interval 20","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"487","properties":{"OBJECTID":487,"wlbNpdidWellbore":496,"wlbName":"34/10-7 R","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 34/10-7 R is a re-entry of well\r\n34/10-7 on the eastern segment of the Gullfaks Field. Well 34/10-7 found oil in\r\nthe Cook and Statfjord formations and performed a drill stem test from the Cook\r\nFormation. The objective of the re-entry was to perform two more drill stem\r\ntests in the main reservoir, the Cook Formation.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 34/10-7 was re-entered with the\r\nsemi-submersible installation Ross Isle on 31 May 1983. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo wire line fluid samples were taken.\r\nCores were cut in the primary well bore.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAfter testing the well was permanently\r\nabandoned on 14 July 1983 as an oil and gas appraisal well.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eTesting\u003c/span\u003e\u003c/b\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe Cook Formation was perforated and\r\ntested at two levels. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eDST 2 tested the interval 1833.4 to\r\n1863.4 m. Towards the end of the main flow it produced 812 Sm3 oil and 99 000\r\nSm3 gas /day through a 40/64" choke. The GOR was 123 Sm3/Sm3, the oil\r\ndensity was 0.826 g/cm3 and the gas gravity was 0.68 (air = 1). The maximum\r\ntemperature recorded at perforation depth was 76.2 deg C. After production\r\ntesting DST 2 included also a seawater injection test and a seawater with\r\nsurfactant injection test. Injection rates of up to 1600 m3/day of seawater\r\nwere recorded during the final stages of the injection sequence. Due to\r\nfracturing of the reservoir during the first phase of injection no conclusions\r\nregarding the effects of the surfactant in the second phase could be made.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eDST 3 tested the interval 1807 to 1821 m.\r\nTowards the end of th","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"488","properties":{"OBJECTID":488,"wlbNpdidWellbore":497,"wlbName":"34/2-2 R","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eExploration well 34/2-2 is located a\r\nnorthwestern part of the Tampen Spur area. It was intended to be the first well\r\nto test the reflections below the Base Cretaceous (Kimmeridgian) Unconformity\r\non a seismically defined, northerly trending west-northwest dipping fault\r\nblock. The well was located near the apex of the structure at the Base\r\nCretaceous level, but down-dip with respect to deeper stratigraphy. Primary\r\ntargets were the Middle Jurassic Brent Formation and the Early Jurassic/Triassic\r\nStatfjord Formation. Secondary targets were possible Early Tertiary and Late\r\nJurassic sandstones. Planned TD was 4300 m Sub Sea. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 34/2-2 R was spudded with the\r\nsemi-submersible installation Sedco 703 on 12 December after the first entry\r\n34/2-2 had been abandoned for technical reasons. The well was drilled to TD at\r\n4074 m in the Late Triassic Statfjord Formation, Raude Member. Bad weather\r\nconditions during wintertime delayed the drilling progress on many occasions. While\r\ndrilling the 36" hole section some problems were encountered due to\r\nboulder beds. An abnormally high wave hit the rig on 16 January, damaging the\r\nliving quarters. The rig had to be shut down for repairs for eleven days.\r\nOtherwise, drilling of the sedimentary sequence below the 30" casing to TD\r\ndid not cause major problems. The well was drilled with spud mud/hi-vis pills\r\ndown to 499 m, with CMC and bentonite from 499 m to 810 m, and with\r\nlignosulphonate mud from 810 m to TD. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe Brent Formation was not developed in\r\nthe well and the reservoir conditions in the Statfjord Formations were found to\r\nbe poorer than expected. No indications of hydrocarbon accumulations were seen.\r\nTrace shows were recorded in the Cretaceous in sandstone stringers from 2405 m\r\nto 2700 m, in siltstones from 2903 m to 3000 m, and in sandstones from 3200 m\r\nto 3282.5 m. From 3282.5 m to 3297.5 m there was a good show in a limestone\r\nbed. No oil shows were reported ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"489","properties":{"OBJECTID":489,"wlbNpdidWellbore":498,"wlbName":"31/6-2 R","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 31/6-2 R is a re-entry of well\r\n31/6-2 gas appraisal well on the south-east periphery of the Troll East gas\r\nprovince. Well 31/6-2 was suspended at 2020 m after drilling through the main\r\ntarget reservoir (Sognefjord Formation) and into the Early Jurassic Drake\r\nFormation. The objectives for 31/6-2 R re-entry were to test the gas column in\r\nthe Sognefjord Formation, and to drill on to the planned Triassic level.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 31/6-2 was re-entered (31/6-2 R)\r\nwith the semi-submersible installation Deepsea Bergen on 31 July 1984 and\r\ndrilled from 2020 m in the Early Jurassic Drake Formation to final TD at 2235 m\r\nin the Late Triassic Hegre Group. The well was drilled with lignosulphonate\r\nmud. Drilling went without significant problems. No cores were cut and no fluid\r\nsamples taken in this well bore.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 8\r\nSeptember 1984 as a gas appraisal.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003ePrior to testing a large amount of steel\r\nparticles and rust, possibly caused by oxidation of casing, was circulated out\r\nof the hole. This caused several days lost time. The rust also created problems\r\nwith valves in the Otis sub-sea test tree and the Pre-Gravel-Pack test string\r\nhad to be pulled because of leakage caused by steel particles in the ball\r\nvalve. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was tested from the interval\r\n1506 m to 1510 m in the middle of the gas column in the Sognefjord Formation,\r\nfirst without gravel-pack and then with gravel-pack. The well flowed 276000 Sm3\r\ngas/day to surface in the pre-gravel-pack test. In the gravel-pack test several\r\nacid-jobs were performed and the flow rate increased after each job. After the\r\nfifth and final acid-job the well produced gas at a rate of 851000 Sm3/day on a\r\n1.5" choke.\u003c/p\u003e\r\n\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"490","properties":{"OBJECTID":490,"wlbNpdidWellbore":499,"wlbName":"31/5-2 R","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\u003cp\u003eWell 31/5-2 R is a re-entry of well\r\n31/5-2. The overall purpose of these wells was to test the reservoir quality, the\r\noil/gas columns, and the hydrocarbon/water contact in the area. The objective\r\nof the re-entry was to undertake drill stem testing of the reservoir.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eAppraisal well 31/5-2 was re-entered\r\n(31/5-2 R) with the semi-submersible installation Treasure Saga. The rig\r\narrived location on 10 June 1984 but due to problems with anchor handling, and\r\non establishing 4 guidelines to well head before running BOP on riser the well was\r\nnot re-entered before 13 June. After the bridge plug was retrieved at 642 m the\r\nhole was circulated with seawater and finally displaced with CaCl brine. Due to\r\nthe complexity of the tests, equipment failures and an unplanned third test,\r\nthe duration of the testing period was 67 days, 42 days longer than prognosed. \u003c/p\u003e\r\n\r\n\u003cp\u003eAfter testing the well was permanently\r\nabandoned on 30 August 1984 as an oil and gas appraisal.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThree drill stem tests were performed.\u003c/p\u003e\r\n\r\n\u003cp\u003eDST 1 tested the interval 1577 - 1581 m and\r\nproduced maximum 1000 m3 oil + water /day trough a 25.4 mm choke. The GOR was\r\n53 Sm3 /Sm3 at 10.3 bar and 60 deg C throughout the test. The corresponding WHP\r\nwas 22 bar with a nitrogen injection rate of 11.5 m/min. The water production\r\nstarted in the beginning and increased continuously through the test. The final\r\nwater cut was 62%. The oil density was 0.896 g/cm3 and the gas gravity (air =\r\n1) was 0.66.\u003c/p\u003e\r\n\r\n\u003cp\u003eDST 2 tested the interval 1574 - 1576 m and\r\nproduced maximum 1290 m3 oil + water/day through 44.5 + 23.8 mm choke. The GOR\r\nwas 53 Sm3 /Sm3 with separator conditions of 3.8 bar and 29degC. The\r\ncorresponding WHP was 15 bar. The water production started after 50 hours of\r\nflow and the water cut increased to 34%. The oil density was 0.89 g/cm3 and the\r\ngas gravity (air = 1) was 0.66.\u003c/p\u003e\r\n\r\n\u003cp\u003eDST 3 tested the interval 1546.5 - 1554.5\r\nm produced","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"491","properties":{"OBJECTID":491,"wlbNpdidWellbore":500,"wlbName":"31/2-5 R","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 31/2-5 is located in the\r\nsouthern part of the oil province in the Troll West area, some 6 km west of the\r\ndiscovery well 31/2-1, in a downthrown fault block. It was drilled in 1980 and\r\nfound a 21 m thick oil zone in excellent reservoir sandstone. The oil column in\r\nthis location was found to be significantly thicker than in other wells in the\r\narea. The objective of the re-entry was to perform a production test in the oil\r\nzone. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 31/2-5 was re-entered\r\n(31/2-5 R) with the semi-submersible installation Borgny Dolphin on 12 June\r\n1981. The cement suspension plug (1204 -1465 m) was drilled out and a test was\r\ncarried out.\u003c/p\u003e\r\n\r\n\u003cp\u003eAfter testing a cement plug was set from\r\n1261 m to 1450 m and again suspended on 20 July 1981.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eOne drill stem test was carried out. The\r\noil zone was perforated from 1582 m to 1588 m and acidized to reduce impairment\r\nof the formation caused by completion fluids. The interval was then tested\r\nthrough gravel pack and produced 906 Sm3 (5700 bbl) oil /day on a 64/64"\r\nchoke. The GOR was 53 Sm3/Sm3 and the oil gravity was 29 deg API. Opening up the\r\nchoke to 2 x 64/64" the rate increased to 1177 Sm3 (7400 bbl)/day and the\r\nGOR increased to 243 Sm3/Sm3. Gas chromatographic analyses of the crude showed\r\na bacterially degraded oil where the n-alkanes were almost absent.\u003c/p\u003e\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"492","properties":{"OBJECTID":492,"wlbNpdidWellbore":501,"wlbName":"31/2-5 R2","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 31/2-5 is located in the\r\nsouthern part of the oil province in the Troll West area, some 6 km west of the\r\ndiscovery well 31/2-1, in a downthrown fault block. It was drilled in 1980 and\r\ntested in the re-entry 31/2-5 R in 1981. The objective of the second re-entry\r\nwas to test and quantify the water mobility (oil-water coning behaviour) in the\r\naquifer zone underlying the oil column to provide input for the Field\r\nDevelopment Plan of the Troll Field.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 31/2-5 R was re-entered\r\n(31/2-5 R2) with the semi-submersible installation Borgny Dolphin on 22 March\r\n1984. The cement suspension plug (1261 m to 1450 m) was drilled out and a test\r\nwas carried out.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 22\r\nApril 1984.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eA 3 m interval directly above the\r\noil-water contact (1566-1569 m SS) was production tested. The test was\r\nconducted in three periods, a cleanup period (PT-2A), a period before acid\r\ntreatment (PT-2B), and a period after acid treatment (PT-2C) The oil sample\r\navailable from the NPD was sampled in PT-2B. The well produced up to 1002 Sm3\r\n(6300 bbl) liquid /day. The water cut decreased in two days from high initial\r\nvalues (> 40%) to a stable value of 20%, independent of the liquid rate. The\r\nstable water cut was apparently controlled exclusively by the relative\r\nmobilities of oil and water. The rate dependence of the Productivity Index,\r\nsignificant before the acid job, almost disappeared after acidizing.\u003c/p\u003e\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"493","properties":{"OBJECTID":493,"wlbNpdidWellbore":502,"wlbName":"31/2-4 R","wlbHistory":"\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 31/2-4 is located some 10 km NNW of\r\nthe discovery well 31/2-1 in a separate fault compartment near the crest of the\r\nJurassic gas accumulation. This crestal area appeared also to coincide with the\r\nculminations of all deeper horizons that could be mapped. The well had two main\r\nobjectives. The first was to appraise the Jurassic gas accumulation in the\r\n31/2-1 Troll Discovery in a location with nearly maximum gross hydrocarbon\r\ncolumn. The well should test lateral variations in this reservoir. The second\r\nmajor objective was to explore deeper Triassic/Palaeozoic Formations. The well\r\nwould test possible hydrocarbon accumulations under the Late Jurassic Troll\r\nreservoir, explore possible pre-Jurassic source rocks, and provide geological\r\nages for deep horizons and thus improve the regional geological setting. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eTD of the well was proposed to be 5000 m\r\nbelow sea level or in Palaeozoic formations whatever came first. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 31/2-4 was originally drilled with\r\nBorgny Dolphin down to 815 m in 1980. The well was however suspended on 13\r\nSeptember 1980 due to a blow out on 34/10-10, where Borgny Dolphin's services\r\nwere immediately required.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 31/2-4 was re-entered (31/2-4 R)\r\nwith the semi-submersible installation Borgny Dolphin on 9 October 1980 and\r\ndrilled to TD at 5035 m in Early Triassic sediments of the Hegre Group. The\r\nwell bore deviation did not exceed 4 deg and at 4693 m, the deepest survey\r\npoint reported, there was only 2 m difference between drilled and true vertical\r\ndepth. The top hole down to 815 m had previously been drilled with seawater and\r\nhi-vis pills. From 815 m to 1280 m the well was drilled with KC/polymer mud,\r\nfrom 1280 m to 1951 m it was drilled wi","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"494","properties":{"OBJECTID":494,"wlbNpdidWellbore":503,"wlbName":"31/2-4 R2","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 31/2-4 was originally drilled with\r\nBorgny Dolphin down to 815 m in 1980. The well was however suspended due to a\r\nblow out on 34/10-10. Well 31/2-4 was re-entered with the same rig in October\r\n1980 and drilled to TD at 5035 m. After Logging at TD the rig went on hire to\r\nShell UK Exploration and Production. The well was suspended in April 1981 for\r\npossible testing and abandonment at a later stage. The decision was made not to\r\ntest the well so the purpose of this second re-entry (31/2-4 R2) was plugging\r\nand permanent abandonment\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 31/2-4 was re-entered for\r\nthe second time (31/2-4 R2) with the semi-submersible installation Borgny\r\nDolphin on 4 November 1982. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was plugged and permanently abandoned\r\non 12 November 1982 as a gas and oil appraisal well.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was performed in the\r\nwell.\u003c/p\u003e\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"495","properties":{"OBJECTID":495,"wlbNpdidWellbore":504,"wlbName":"31/2-2 R","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 31/2-2 R is a re-entry of well\r\n31/2-2, which was suspended due to rig repair after setting the 9 5/8"\r\ncasing. The aim of the re-entry was to drill through the Jurassic and into the\r\nTriassic, and to conduct a drill stem test in the Late Jurassic oil and gas\r\nzones. The oil test was considered very important and should replace the\r\nabandoned test of the oil zone in well 31/2-1.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 31/2-2 was re-entered (31/2-2 R)\r\nwith the semi-submersible installation West Venture on 2 June 1980. The\r\nre-entry depth was 1857 m and new formation was drilled to TD at 2600 m in the\r\nTriassic Hegre Group. The testing phase was interrupted by a 31 days strike\r\nfrom 14 July 1980. The well was drilled with gel and lignosulphonate from the\r\nre-entry point to TD. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe well below re-entry depth consisted\r\nof well-developed Middle to Early Jurassic sequences (Brent and Dunlin Groups,\r\nStatfjord Formation) and 100 m of Triassic Hegre Group sediments before TD was\r\nreached.\u003c/p\u003e\r\n\r\n\u003cp\u003eAfter plugging the well it proved\r\nimpossible to retrieve the Temporary Guide Base, which was left on the se\r\nfloor, below the mud line in a crater. The well was permanently abandoned on 6\r\nOctober 1980 as a gas and oil appraisal.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eA full production test was carried out\r\nover three intervals in order to test both the oil zone from 1579 m to 1591 m\r\nand the gas zone from 1544 m to 1579 m.\u003c/p\u003e\r\n\r\n\u003cp\u003eTest #1 from the interval 1586.5 m to\r\n1588.5 m tested the oil zone, and a gravel pack completion and regular\r\nproduction string were used. A total of 42 days were spent on this test as it\r\nwas of extreme importance to get this zone properly tested. A maximum flow rate\r\nof 132 Sm3 oil/day at a GOR of 53 Sm3/Sm3 was obtained during 24 hours after\r\nacid stimulation of the well, but it declined to 76 Sm3/day during the next\r\ndays. At this point operations were interrupted for a month by the strike.\r\nAfter the strike a further test of t","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"496","properties":{"OBJECTID":496,"wlbNpdidWellbore":505,"wlbName":"31/2-1 R","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 31/2-1 R is the re-entry of well\r\n31/2-1, the Troll West discovery well. Originally the re-entry was intended for\r\ntesting of a possible oil zone, but this plan was dropped in favour of a DST in\r\nwell 31/2-2, situated in a more optimal position with regard to a possible\r\noil-leg. The only objective for 31/2-1 R was thus permanent plugging and\r\nabandonment. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 31/2-1 was re-entered (31/2-1 R)\r\nwith the semi-submersible installation Borgny Dolphin on 26 October 1981.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was plugged and abandoned on 9\r\nNovember 1981.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was performed.\u003c/p\u003e\r\n\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"497","properties":{"OBJECTID":497,"wlbNpdidWellbore":506,"wlbName":"30/7-8 R","wlbHistory":"\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 30/7-8 R is a re-entry of well\r\n30/7-8, which was suspended with TD at 4287 m due to technical problems, without\r\nfulfilling the well objectives. The well was drilled on the Norwegian part of\r\nthe Shetland Basin in the northern North Sea. The objectives were to test the\r\nhydrocarbon potential in the Middle Jurassic Brent Group (primary objective),\r\nand the Early Jurassic Cook Formation and Statfjord Group (secondary objectives).\r\n\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 30/7-8 was re-entered with\r\nthe semi-submersible installation Treasure Seeker on 23 November 1980. It was\r\nkicked off at 3755 m and drilled to final TD at 4813 m in the Late Triassic\r\nHegre Group. No significant problem was encountered in the operations. The well\r\nwas drilled with Spersene/XP-20/Resinex/Drispac water based mud from kick-off to\r\nTD. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe primary target reservoir, Tarbert\r\nFormation came in at 4058 m. It contained gas condensate with a gas/water\r\ncontact at 4112 +/- 5 m, based on pressure gradients. Shows were described on\r\ncuttings and cores over the interval 4489.3 to 4555 m in the Statfjord Group,\r\nNansen Formation.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eTen cores were cut in the well. Cores 1 -\r\n8 were cut from 4062.3 m to 4159.3 m in the primary target Tarbert Formation\r\nsandstones, while cores nine and ten were cut in the intervals 4489.3 to 4502.5\r\nm and 4527.1 to 4540.6 m, both in the Statfjord Group. The core depths are 4-5\r\nm deeper than the logger depths. RFT fluid samples from 4105 m recovered gas,\r\ncondensate, water and mud filtrate.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was permanently abandoned on 29\r\nJanuary 1982 as a gas/condensate discovery.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eTesting\u003c/span\u003e\u003c/b\u003e","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"498","properties":{"OBJECTID":498,"wlbNpdidWellbore":507,"wlbName":"30/7-6 R","wlbHistory":"\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 30/7-6 R was originally named 30/7-6\r\nPhase II by the operator group. It is a re-entry of well 30/7-6, which was\r\nsuspended at a final depth of 3711 m after taking a massive gas kick at the\r\nbase of the Heather Formation. The well is located on the East Shetland Basin\r\nin the North Sea close to the UK border. The main objective of the re-entry was\r\nEarly and Middle Jurassic sandstones. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 30/7-6 was re-entered with\r\nthe semi-submersible installation Treasure Seeker on 18 April 1978. The 7"\r\nliner shoe at 3707 m was drilled out with a 6" bit using 1.92 sp.gr. mud. A\r\nsmall influx of gas was encountered while drilling into the high-pressured\r\nreservoir sand at 3810 m. The gas influx was circulated out and the mud weight\r\nincreased to 1.98 sp.gr. After several circulations, the mud density was raised\r\nto 2.04 sp.gr. Two days elapsed in conditioning and stabilizing the well. Further\r\ndrilling proceeded without significant problems to TD at 4115 m in the Early Jurassic\r\nDrake Formation. The well was drilled with a fresh water gel/chromium-lignosulphonate\r\nmud system from 3707 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe 30/7-6 well encountered the gas\r\ncondensate bearing sandstones of Middle Jurassic age (Tarbert Formation) at\r\n3792 m. The reservoir continued with interbeds of shales and coals down to the\r\ndeepest sandstone at 3892 m in the top of the Ness Formation. Net sandstone in\r\nthe interval is 75 m based on wire line log evaluation. No hydrocarbon-water\r\ncontact was penetrated in the well. Average porosity is calculated to 19.4% and\r\naverage water saturation to 20%. No shows were described below the hydrocarbon\r\nbearing reservoir.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo conventional cores were cut in the\r\nwell. RFT","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"499","properties":{"OBJECTID":499,"wlbNpdidWellbore":508,"wlbName":"30/3-2 R","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 30/3-2 R is a re-entry of well\r\n30/3-2, which was suspended at 955 m in Miocene sediments due to a strike. It is\r\nlocated ca 7 km north of the Oseberg Field in the Northern North Sea. The\r\nprimary objective of the well was to test sandstones belonging to the Brent and\r\nDunlin group. Secondary objective was sandstones in the Statfjord formation. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 30/3-2 was re-entered with\r\nthe semi-submersible installation Deepsea Bergen on 2 September 1980 and drilled to TD at 3567 m in the Triassic Lunde Formation. The\r\nre-entry well track was drilled first with gel/lignosulphonate in 12 1/4" pilot\r\nhole from 955 m to 2350. Severe problems were experienced when opening up the\r\npilot hole to 17 1/2". The mud system was changed, and a gypsum system was\r\nchosen. This change made it possible to complete the 17 1/2" section, but\r\nseveral days were lost due to hole problems and problems with the draw-works\r\ncontrol circuits. The rest of the well was drilled with a\r\ngypsum/lignosulphonate mud and proceeded according to the program.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe Brent group was encountered at 2825 m\r\nand consisted of the Ness Formation down to 2878 m and the Etive Formation from\r\n2878 m to top Dunlin Group at 2949.5 m. The Statfjord Formation was encountered\r\nat 3228 m. The Brent Group contained two separate hydrocarbon-bearing reservoirs\r\nwith one oil/water contact at 2839 m in the Ness formation, and another at 2932\r\nm in the Oseberg Formation. RFT data also indicated a light hydrocarbon gradient\r\n(0.433 g/cc) in a 7 m thick Intra Dunlin (Cook) sand at 3071 m. The character\r\nof the fluorescence seen on this sand indicated gas. Frequent but discontinuous\r\noil shows on limestone and claystone were observed beginning at 1930 m and down\r\nthrough Paleocene, Cretaceous and Late Jurassic to top reservoir in the Brent\r\nGroup. Below OWC shows on sandstones were observed down to 3339 m.\u003c/p\u003e\r\n\r\n\u003cp\u003eA total of 148 m core was recovered in 12\r\ncores in th","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"500","properties":{"OBJECTID":500,"wlbNpdidWellbore":509,"wlbName":"30/3-1 R","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 30/3-1 R is located just north of\r\nthe Huldra Discovery. The primary well bore 30/3-1 was drilled in 1979 to a\r\ntotal depth of 3718 m where it was suspended due to an unexpected pressure\r\nbuild-up in the Early Cretaceous. The purpose of well 30/3-1 R was to re-enter\r\nthe previously abandoned well and continue drilling beneath the 9 5/8"\r\ncasing shoe to test sandstones in the Brent Group. Secondary objectives were\r\nsandstones in the Early Jurassic, Cook and Statfjord formations. Well 30/3-1 R\r\n(Phase 2) was planned to be drilled 50 m into the Triassic to a total prognosed\r\ndepth of 4825 m.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 30/3-1 R was re-entered by\r\nthe semi-submersible installation Dyvi Delta on 1 January 1982 and drilled to\r\nTD at 4421 m (4395 m TVD) in Late Triassic sediments in the Statfjord\r\nFormation. After the 9 5/8" casing had been drilled and cleaned out for\r\ncement plugs the string was lost in the hole when running in with a new bit.\r\nAfter several attempts to retrieve the fish, the hole was plugged back. A\r\nwindow was cut in the 9 5/8" casing from 3657 m to 3672 m and the hole was\r\nkicked off from this depth after problems with lost circulation had been\r\nsolved. While drilling of the last part of the 8 1/2" hole several\r\nincidents of stuck pipe was experienced. This section was plugged back with\r\ncement. When displacing the second cement plug, the pipe got stuck. After\r\ncutting the 5" drill pipe an influx (gas and water) from the top of the\r\nStatfjord Formation was taken. The well built a deviation with maximum of 20.5°\r\nat 4165 m. The well was drilled with a Spersene XP 20/Magcogel/nut plug mud\r\nsystem from kick-off to TD. \u003c/p\u003e\r\n\r\n\u003cp\u003eHydrocarbons were encountered in thin\r\nsandstones interbedded with limestone, coals and claystones over the interval from\r\n3762 m to 3861 m in the Ness, Etive, and Rannoch formations in the Brent group.\r\nOne core was cut from 3863.6 m to 3875.2 m in the Brent Group. No fluid sample\r\nw","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"501","properties":{"OBJECTID":501,"wlbNpdidWellbore":510,"wlbName":"25/10-4 R","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThis well was drilled in two phases, a\r\nprimary well bore 25/10-4, and a re-entry well bore 25/10-4 R. The well was\r\ndrilled in the western part of the Balder Field in the North Sea. The primary\r\nobjective was to establish the presence of a thick accumulation of Paleocene\r\noil sand, and evaluate sand-shale distribution and reservoir quality. The top\r\nof the reservoir was anticipated to be at 1698 m subsea. As a secondary\r\nhigh-risk objective, the well was to be drilled to 2700 m to test for the\r\npresence of hydrocarbons in the Permian. This test was necessary as any\r\nhydrocarbons present could critically affect the design and location of a\r\npossible production platform.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eAppraisal well 25/10-4 was spudded with\r\nthe semi-submersible installation Glomar Biscay II on 8 December 1980 and\r\ndrilled to TD at 2348 m in the Late Permian Zechstein Group where the well was\r\nsuspended due at 18 January 1981 due to a pressing need for the rig to drill\r\nother Balder Field delineation wells, combined with unexpected delays in the\r\n25/10-4 well progress as a result of lost circulation. The re-entry commenced\r\non 29 May 1981 and deepened the well to 2550 m in a massive unconsolidated sand\r\nof Permian/ Carboniferous age. The top hole down to 30" casing depth at\r\n214 m was drilled with seawater. Below 214 m the well, including the re-entry\r\nwell, was drilled with seawater/gels/lignosulphonate.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe main oil sand of Paleocene age was\r\nencountered between 1759.5 m and 1784.0 m. The net oil sand was 22 m thick. The\r\nTriassic section had several thin and oil-bearing sandstones not detected\r\nbefore in the area. A wire line FIT in one of these sands proved live oil. In\r\ntotal these sandstones made up 21 m net sand but the accumulation was\r\nconsidered insignificant. Cuttings from 2130 m (Early Jurassic) through Permian\r\nZechstein and the upper part of the Permian/Carboniferous unconsolidated\r\nsandstone contained traces/shows of hydrocarbons.\u003c/p\u003e","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"502","properties":{"OBJECTID":502,"wlbNpdidWellbore":511,"wlbName":"25/10-2 R","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 25/10-2 was\r\ndrilled to test a structural closure on the down faulted west flank of the\r\nbasement high on which Esso wells 25/11-1 (Balder Discovery well), 25/8-1 and\r\n25/10-1 had been drilled. The original\r\nprimary objective, as stated in the Operator's Final Well Report from 1972, was\r\nEarly Paleocene to Late Eocene sands, which had a thin oil leg in the three\r\nwells drilled previously. It was\r\nanticipated that appreciably thicker Early Eocene sands would be encountered in\r\nthe oil leg of 25/10-2. Additional prospects were in Middle - Late Eocene\r\nsands, Danian carbonates, and sands of Early Cretaceous, Jurassic or Triassic\r\nage. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe results of the\r\nwell given below is reported with today's knowledge of the area (anno 2003) and\r\ncannot be compared directly with the original objectives.\u003c/p\u003e\r\n\r\n\u003cp\u003e \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 25/10-2\r\nwas spudded with the drilling vessel "Glomar Grand Isle" on 5 August\r\n1970 and drilled to TD at 2191 m (7187 feet) in the Paleocene Lista Formation.\r\nDrilling operations went without mechanical problems and there was no lost time\r\nwaiting on weather. Well 25/10-2 was suspended 25 August 1970 as a well with\r\noil shows. The well was re-entered (25/10-2 R) using "Glomar Grand\r\nIsle" on 2 May 1972 and drilled to a total depth of 3180.6 m (10435 feet)\r\nin basement rock. \u003c/p\u003e\r\n\r\n\u003cp\u003eAfter drilling out\r\nthe plug in the bottom of the casing in the re-entry some difficulty was\r\nexperienced in staying in the old hole.\r\nThe well was drilled to a depth of 2369 m where lost circulation was\r\nencountered. Later the pipe became stuck, with the bottom of the fish at 2213\r\nm, and it became necessary to sidetrack the hole. Six cones were lost in the hole while drilling at 2497 m in the\r\nsidetrack hole; otherwise no problems were experienced. Initial drilling from\r\nthe sea floor to 396 m was with seawater and gel. From 396 m to 1036 m the hole\r\nwas drilled with seawater / Spersene / XP 20 / Salinex s","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"503","properties":{"OBJECTID":503,"wlbNpdidWellbore":512,"wlbName":"25/10-1 R","wlbHistory":"\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 25/10-1 R is a re-entry of well\r\n25/10-1, which found strong shows in thin Early Eocene sands, but was suspended\r\nat top Paleocene level due to heavy autumn storms. The purpose of the re-entry was\r\nto test the Early Eocene sands and to extend the well into deeper Paleocene\r\nsands, which were anticipated to be oil-bearing.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eAppraisal well 25/10-1 was re-entered (25/10-1\r\nR) with the vessel Glomar Grand Isle on 9 July 1970. The re-entry well was\r\nkicked off at 1664 m in 25/10-1 and drilled to final TD at 2091 m in the Early\r\nJurassic Statfjord Formation. No significant problems were encountered in the\r\noperations. The well was drilled with seawater/spersene XP-20, Splinex mud from\r\nkick-off to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eFrom kick-off down to 1747 m the well\r\ndrilled the same lithology as the primary well. The underlying Paleocene\r\nsection was composed of sands and shales, with the sand bed thicknesses ranging\r\nfrom about 4 to 40 m. These Paleocene sands were highly porous and permeable,\r\nbut only the top 5 m had good oil shows and this section produced water only on\r\nwire line formation test. The Paleocene section rested directly on the Early\r\nJurassic Statfjord Formation. Sands within the Statfjord Formation were of\r\nreservoir quality, but were water-wet with only streaks of non-fluorescing dead\r\noil.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe section from 1731 to 1804.1 m was cored\r\nall through in five cores, with near 100% total recovery. The upper two of\r\nthese (core #9 and #10) were partially overlapping with the lower three cores\r\n(core #6, #7, and #8) in well 25/10-1. A total of twelve wire line FIT samples\r\nwere attempted and five of them were reported to contain formation fluid. FIT\r\nno 1 and 2 were taken in the Paleocene sands (Heimdal Formation) at 1789.2 m and\r\n1778.2 m. These recovered only water and mud. The remaining successful FIT recovered\r\nhydrocarbons: FIT no 4 at 1760.8 m (Heimdal Formation) recovered gas and 4800\r\ncm3 oil, FIT no 6 at 1762.4 m (Heimd","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"504","properties":{"OBJECTID":504,"wlbNpdidWellbore":513,"wlbName":"24/12-1 R","wlbHistory":"\u003chtml\u003e\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 24/12-1 R is located on the Gudrun\r\nTerrace, about 15 km east of British sector. The purpose of the well was to\r\nevaluate a seismic closure, named Gamma, in the southern part of the Block. The\r\nmain objective was the Middle Jurassic sands. Well 24/12-1 R is a re-entry of\r\nwell 24/12-1, which was suspended after setting the 9 5/8" casing at a TD\r\nof 3966 m in the Early Cretaceous. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 24/12-1 R was spudded with\r\nthe semi-submersible installation Treasure Seeker on 7 June 1978 and drilled to\r\nTD at 4825 meter in the Triassic Group. Three cement plugs were drilled\r\nin the 9 5/8" casing using the existing mud left in the hole before\r\nre-entry. The 9 5/8" casing shoe was drilled out at 3966 meters using 1.93\r\n- 1.94 R.D. mud weight. After drilling the shoe, circulation and rotation\r\nstopped as the pipe stuck at 3968 meters. The pipe was freed and pipe rubbers\r\nthat had been stripped were circulated out. Resumed drilling and raised mud wt.\r\nto 2.00 R.D. Ran core barrel from 4160 meters to 4182 meters, after running\r\ncore barrel raised mud weight in active system to 2.04 R.D. due to background\r\ngas. Turbine drilling was continued to TD. When the sub sea assembly was pulled\r\nwhen abandoning the well it was realized that the rig for some time during the\r\noperation must have been off location. Severe wear on the flex-joint and bag\r\npreventers was discovered. This probable rig offset also caused several of the\r\ndrill pipe rubber protectors to be torn off, which probably caused the stuck\r\npipe at 3968 m. The rubbers were circulated out of the hole during several days\r\nand caused directly or indirectly many days of lost rig-time. The well was\r\ndrilled with a Spersene / XP-20 / Resinex lignosulphonate / lignite mud system\r\nfrom re-entry depth to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe Late Jurassic Draupne Formation was\r\nencountered at 4055 m and was 85 m thick. Below this depth 210 m of alternating\r\nHeather Formation shale and Intra ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"505","properties":{"OBJECTID":505,"wlbNpdidWellbore":514,"wlbName":"17/12-1 R","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eExploration well 17/12-1R was drilled on\r\nthe northern margin of the Egersund Basin in the North Sea, towards the Åsta\r\nGraben. Its primary target was Jurassic sands with estimated top at 2161 m\r\n(7090 feet) and with 61 m (200 feet) thickness. Sand developments within the\r\nEarly Cretaceous and Triassic sections were regarded as secondary objectives.\r\nPlanned TD was 8 m (25 feet) into the Zechstein salt.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe top hole down to TD in the 26"\r\nsection at 458 m, well 17/12-1, had been spudded and drilled the year before by\r\nthe jack-up installation Mærsk Explorer.\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 17/12-1R is Reference Well for the\r\nEgersund Formation.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell\u00A0\u00A0 17/12-1 was re-entered (17/12-1R)\r\nwith the semi-submersible installation Ocean Viking on 14 March 1972 and\r\ndrilled to TD at 4298 m, 165 m into the Late Permian Zechstein Formation. The\r\nwell bore was drilled water based with a 3 % - 6 % diesel addition.\u003c/p\u003e\r\n\r\n\u003cp\u003eTop of the primary reservoir target was\r\nencountered in the Middle Jurassic at 2292 m. The reservoir section contained\r\nseveral sands separated by mudstone beds. The two uppermost sands in the\r\nSandnes Formation were water wet. The next two sands below, in the Bryne\r\nFormation, yielded 162 Sm3 oil/day on a six hours test. The tests indicated an\r\nOWC between DST 1 and DST 7, i.e between 2337.2 m and 2344 m. No sands were\r\nencountered in the Early Cretaceous and sand development within the Triassic\r\nwas limited to thin, fine to course grained, continental-type clastic beds. No\r\nconventional cores were cut and no fluid samples were taken on wire line.\r\nTwenty-six sidewall cores were recovered in the interval 1371 m to 2382 m.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 21\r\nJune 1972 as an oil discovery.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThree out of 7 DST's produced oil and gas\r\nto surface. \u003c/p\u003e\r\n\r\n\u003cp\u003eDST 1 perforated the interval 2337.2 m to\r\n2341.4 m and produced 141 Sm3 oil /day on a 12/64" choke. GOR was 20.5\r\nSm3/Sm3 a","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"506","properties":{"OBJECTID":506,"wlbNpdidWellbore":515,"wlbName":"17/9-1 R","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 17/9-1R is located in the Åsta\r\nGraben in the North Sea, ca 30 km north of the 17/12-1R Bream Discovery well.\r\nThe primary objective was to evaluate sands at the base of the Jurassic\r\nsequence. The structure is not associated with mobile salt, which is the case\r\nfor the Bream Discovery. The first entry was suspended on 6 November 1973 at\r\n2816 m when the riser was lost in a storm. The re-entry 17/9-1R was made to\r\nrecover and repair the damaged stack on the sea floor. A deeping program was\r\ndesigned to 3658 m to test the Triassic and possible Zechstein sand intervals.\r\nAlso a complete logging program was designed to include the portion of original\r\nhole below 2616 m, which was not logged due to storm damage to drill ship.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 17/9-1 was re-entered (17/9-1R) with\r\nthe drill ship Glomar Grand Isle on 12 May 1974. The broken BOP stack left on\r\nthe original hole was recovered and repaired by divers. A total of 7 days and\r\n11 lock-out dives in 159 m water depth were required for these operations.\r\nAfter successful re-entry well bore 17/9-1R was drilled to TD at 3161 m in Late\r\nTriassic sand and shale of the Skagerrak Formation. The well bore was drilled\r\nwith a lignosulphonate/seawater mud from re-entry point to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe upper section of the Skagerrak\r\nFormation, from 2999.2 m to 3029.7 m, had sandstone with apparent porosity and\r\nquestionable traces of dead oil. Sands penetrated in the interval from 3109 m\r\nto TD had no shows. The sands were found in thin zones and the potential\r\nreservoir quality was considered very poor. Organic geochemical analyses\r\ndetected no significant source rock potential in the re-entry; the Late\r\nJurassic shales penetrated in the first entry (17/9-1) thus remain as the only\r\nsignificant source rock in the total well bore. The well was found immature;\r\npossibly marginally mature towards the Late Triassic at TD (%Ro = 0.5). One\r\norganic geochemical study (Robertson Research) inferred "traces","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"507","properties":{"OBJECTID":507,"wlbNpdidWellbore":516,"wlbName":"15/9-12 R","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 15/9-12 R is a re-entry of well\r\n15/9-12, which was drilled as an appraisal well on the saddle area between the\r\nAlpha and Beta structures on the Sleipner Vest field in the North Sea. Due to\r\ntechnical problems with the rig the final testing was not done in the primary\r\nwell. The purpose of the re-entry was testing and plugging. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 15/9-12 was re-entered on 29 March\r\n1982 with the semi-submersible installation Deepsea Saga. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003e\u00A0After testing the well was permanently\r\nabandoned on 27 April 1982 as a gas-condensate appraisal well.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eTesting\u003c/span\u003e\u003c/b\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThree Drill Stem Tests were conducted.\r\nDST 1A tested the interval 3585 m 3595 m. This test was aborted due to bad\r\nweather after flowing the well for 150 minutes. The interval was retested a few\r\ndays later in DST 1B. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eDST 1B flowed 252 Sm3 condensate and\r\n771600 Sm3 gas /day through a 64/64" choke. The condensate/gas ratio (CGR)\r\nwas 3056 Sm3/Sm3, the condensate density was 0.793 g/cm3, and the gas gravity\r\nwas 0.772 (air = 1) with ca 8% CO2. The DST temperature was 121 deg C at gauge\r\ndepth 3561.8 m.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eDST 2 tested the interval 3512 m to 3522\r\nm. It flowed 231 Sm3 condensate and 808500 Sm3 gas /day through a 64/64"\r\nchoke. The CGR was 3495 Sm3/Sm3, the condensate density was 0.793 g/cm3, and\r\nthe gas gravity was 0.765 (air = 1) with ca 7% CO2. The DST temperature was 119\r\ndeg C at gauge depth 3499 m.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eEight gas samples and six condensate\r\nsamples were taken at the separator during DST 1. E","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"508","properties":{"OBJECTID":508,"wlbNpdidWellbore":517,"wlbName":"15/6-2 R","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 15/6-2 R is a re-entry of\u00A0 well\r\n15/6-2 in the Ve Sub-basin in the North Sea, ca 5 km north of the Sleipner\r\nField. The initial well 16/6-2 was drilled to 3131 m in the Shetland Group with\r\nthe drill vessel Glomar Grand Isle. The well found good shows in Paleocene\r\nsandstones and was suspended in October 1971. The primary objective of the re-entry\r\nwas to deepen the well and test the Dogger (Middle Jurassic) deltaic sands. A\r\nsecondary objective was to test the Lias section (Early Jurassic).\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 15/6-2 re-entered on 9 May\r\n1974. It was drilled with the semi-submersible installation Drillmaster to TD\r\nat 4779 m in the Late Permian Zechstein Group. The pipe stuck temporarily three\r\ntimes in intervals below 4602 m. Due to hole problems and tight spots no logs\r\nwere run below 4611 m The well was drilled with a seawater /lignosulphonate mud\r\nfrom re-entry point to TD. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe only hydrocarbon reservoir penetrated\r\nwas the Dogger gas-condensate sands from 3582 to 3641 m. The lower part of\r\nDogger section and all of the Lias section were cut out of this test by an\r\nerosional unconformity and/or faulting. The missing interval has good potential\r\nfor additional reservoir quality sands. In addition, the Late Triassic has good\r\nsand development that could be adequate for reservoiring hydrocarbons. During\r\nthe drilling of the Triassic and Permian section (3688 to TD), the background\r\ngas in mud and cuttings was near zero, which probably is related to lack of\r\nsource material for hydrocarbons.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo shows were recorded except in Dogger.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eFive cores were cut with 100% recovery in\r\nthe interval 3582.3 to 3641.1 m. A total of eigh","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"509","properties":{"OBJECTID":509,"wlbNpdidWellbore":518,"wlbName":"7/12-4 R","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 7/12-4 R is a re-entry of well\r\nappraisal well 7/12-4 on the Ula Field. Well 7/12-4 proved oil in the eastern\r\nflank of the Ula structure and was suspended as a possible producer. The\r\npurpose of the re-entry was permanent plugging and abandonment. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 7/12-4 was re-entered using the was\r\nspudded with the semi-submersible installation Dyvi Alpha on 16 March 1984 \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was plugged and permanently\r\nabandoned on 20 March 1986.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eTesting\u003c/span\u003e\u003c/b\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo drill stem test was performed. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"510","properties":{"OBJECTID":510,"wlbNpdidWellbore":519,"wlbName":"7/11-7 R","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 7/11-7 SR is a re-entry of\r\nexploration well 7/11-7 S, drilled from the Cod platform and suspended in\r\nDecember 1983, after testing of Jurassic, Triassic, and Permian targets. The\r\nobjective of the re-entry was to utilize the well as a development well for the\r\nmain Paleocene Cod reservoir.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell bore 7/11-7 S was re-entered (7/11-7\r\nSR) from the fixed installation Cod installation on 29 September 1984. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was completed on 8 October 1984\r\nand reclassified to development well 7/11-A6.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was performed in the\r\nwell.\u003c/p\u003e\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"511","properties":{"OBJECTID":511,"wlbNpdidWellbore":521,"wlbName":"7121/1-1","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 7121/1-1 was\r\ndrilled on the Loppa High in the northern part of the Tromsøflaket area,\r\noffshore Northern Norway. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe primary\r\nobjective of the 7121/1-1 exploration well was to test the reservoir and\r\nhydrocarbon potential of a possible Early Permian (Artinskian) mounded\r\ncarbonate facies (biohermal build-ups) identified by seismic. Secondary\r\nobjectives were Late Permian carbonates and Early Carboniferous to Devonian\r\nsandstones, Late Carboniferous - Early Permian carbonates, and Triassic\r\nsandstones. Finally, the exploration well was designed to fulfill the license's\r\nobligatory work program which committed the licensees to drill one wildcat well\r\nto test prospects down to rocks of Devonian age or 5000 m, whichever came\r\nfirst. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eExploration well\r\n7121/1-1 was spudded on 10 October 1985 in 369 m water depth with the\r\nsemi-submersible installation "Zapata Ugland". Due to NPD winter\r\nseason regulations drilling was stopped at 916 m. Drilling of well 7121/1-1R\r\ncommenced on 19 March 1986 and reached total depth of 5000 m in Late\r\nCarboniferous sediments of the Ørn Formation. The well was drilled with sea\r\nwater and gel down to 1978 m, and with Sea water / gel / polymer from 1978 m to\r\nTD. Lost Circulation Material was used below 3370 m. Triassic rocks were\r\nencountered at 698 m, unconformably underlying 178 meters of Tertiary claystone\r\nand siltstone. The Triassic sediments (2295 m thick) consisted predominantly of\r\nvery fine clastics with minor interbeds of sandstone, stringers of dolomite and\r\nlimestone and traces of coal.\u003c/p\u003e\r\n\r\n\u003cp\u003eFair to poor\r\nhydrocarbon shows were encountered in some thin and tight sandstones of Late\r\nand Middle Triassic age. The only significant hydrocarbon show was encountered\r\nin a 11.5 m thick sandstone bed, between 1932.0 and 1943.5 m, where 18.7 % gas\r\n(C1 & C4) was measured by the gas detectors. The Paleozoic section (Permian -\r\nLate Carboniferous Ørn Formation) was encountered at 2","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"512","properties":{"OBJECTID":512,"wlbNpdidWellbore":522,"wlbName":"6407/6-2","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 6407/6-2 was drilled on a structure\r\nin the western part of the block. The structure has two distinct highs, and the\r\ntarget for this well was on the northern high. The primary objective for the\r\nwell was to test possible hydrocarbon accumulation in sandstones of middle\r\nJurassic age (Fangst Group). Secondary objectives were seen in sands near base\r\nCretaceous (Cromer Knoll Group), in Early Jurassic sandstones (Tilje\r\nFormation), in sandstones within the Åre Formation, and in the Triassic Grey-\r\nand Red Beds. The top hole and Tertiary sections of this well were expected to\r\ncontain shallow gas, possibly at a depth of 570 m. Possibly, also swelling,\r\noverpressured Early Eocene Red/Brown claystone could be encountered. The\r\nprognosed depth was 4150 m, or rocks of Triassic age.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 6407/6-2 was spudded with\r\nthe semi-submersible installation West Vanguard on 4 October 1985. It was\r\nabandoned at a depth of 523 m due to a blow out. The blow out probably was\r\ncaused by gas from a shallow sand pocket at 505 m. Gas samples from the blow\r\nout were analysed and found to be gas generated by bacteria at shallow depths.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe 20" casing had not yet been set\r\nso the blow-out preventer (BOP) had not been installed when the incident\r\nhappened. At 20:50 hours in the evening an increase in the penetration rate\r\nfrom 40 to 700 m/hour was observed. Drilling was immediately stopped and the\r\nbit pulled out of hole. The hole was circulated for 35 minutes. A 3-m3 mud loss\r\nwas observed. After gas had been circulated out drilling of a 12 1/4"\r\npilot commenced from 508 m to 516 m. Here background gas again increased. After\r\nagain circulating out the gas drilling continued to 524 m where the drill\r\nstring was pulled out 15 m for a new stand connection. The well now started\r\nflowing uncontrolled and pumping of kill mud started. This did not stop the\r\nblow out. Gas flowed onto the deck of the rig and at 23:20 hours the gas\r\nexploded.","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"513","properties":{"OBJECTID":513,"wlbNpdidWellbore":523,"wlbName":"34/10-25","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 34/10-25 was drilled to\r\ntest possible shallow gas accumulation in sandstones at the location for the\r\nGullfaks B platform. The targets were several sand layers of Pliocene age. Gas had\r\nbeen indicated on seismic anomalies and logs from other wells in the same\r\nfield.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 34/10 was spudded with the\r\nsemi-submersible installation Deepsea Bergen on 6 August 1985 and drilled to TD\r\nat 600 m in Pliocene sediments in the Nordland Group. No significant problem\r\nwas encountered in the operations. The well was drilled with water based mud.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eTop Pliocene was encountered at 302 m. No\r\nindication of shallow gas was observed in the well. The well penetrated one sand\r\nlayer only, from 518.9 to 522 m. The sand was water bearing. Biostratigraphical\r\ninvestigations proved only fauna of Pleistocene and Pliocene age.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo cores were cut and no wire line fluid\r\nsamples were taken. A full set of conventional logs where run. Maximum bottom\r\nhole temperature on wire line, measured 4 hours after circulation was 29.4 deg\r\nC. Cuttings samples were taken every 5 m from 230 m to TD. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was permanently abandoned on 17\r\nAugust 1985.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eTesting\u003c/span\u003e\u003c/b\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo drill stem test was performed.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"514","properties":{"OBJECTID":514,"wlbNpdidWellbore":524,"wlbName":"25/6-1","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 25/6-1 was\r\ndrilled on the northeastern part of the Utsira High. The main objective of the\r\nwell was to test for hydrocarbons in a prospect west of the main fault in the\r\nsouthern part of the block. Primary targets were the Middle Jurassic reservoir\r\nsandstone belonging to the Vestland Group, which is partly eroded in this area,\r\nand the Early Jurassic Statfjord Formation sandstone. Secondary objective was\r\nthe Early Tertiary sandstone. The total depth target was to drill through a\r\nstrong seismic reflector between 2.5 and 2.6 second TWT. Shallow gas was\r\nexpected at 282 to 344 m and 395 m.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 25/6-1\r\nwas spudded 18 December 1985 by Wilh. Wilhelmsen's Offshore Services\r\nsemi-submersible installation Treasure Saga, and completed 3 February 1986 at a\r\ndepth of 2881, 30 m into rocks of probably Early Palaeozoic/Pre-Cambrian\r\nage. The well was drilled with seawater\r\nand hi-vis pills down to 260 m, with bentonite gel mud from 260 m to 1028 m,\r\nwith gypsum/polymer mud fro 1028 m to 2195 m, and with bentonite gel / polymer\r\nmud from 2195 m to TD. No shallow gas was encountered.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe\r\nQuaternary/Tertiary sequence was 2017 m thick, and consisted of the Nordland,\r\nHordaland, and Rogaland Groups. The Nordland Group was marine claystone with\r\nsands frequently developed, especially in the lower part, with 163 m of the\r\nsandy Utsira Formation. The Hordaland Group was clay/claystone with some thin\r\nsand units. Slightly tuffaceous claystone and a lower sand/marl/ claystone\r\nsequence were the main lithologies of the Rogaland Group. A 65.5 m thick\r\nCretaceous sequence represented by Shetland and Cromer Knoll Groups was\r\npenetrated. The main lithology was chalky limestone, calcareous claystone\r\ngrading to marl and minor sand.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe Jurassic\r\nsediments represented by the Viking, Vestland, and Dunlin Groups and the\r\nStatfjord Formation were encountered at 2233.5 m.\u00A0 Top Vestland Group was at 2277 m and top Statfjord Formation","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"515","properties":{"OBJECTID":515,"wlbNpdidWellbore":525,"wlbName":"34/7-7","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 34/7-7 was drilled on the western\r\nside of the “Inner Main Fault” near the geographic centre of the Snorre Field.\r\nThe objectives were to test the reservoir quality of the Statfjord Group and\r\nthe Oil-Water Contact, expected to be at 2611 m. Further objectives were to\r\ntest the subdivision and reservoir characteristics of the Triassic Lunde Formation.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 34/7-7 was spudded with the\r\nsemi-submersible installation Treasure Saga on 17 September 1985 and drilled to\r\nTD at 3526 m in the Late Triassic Lunde Formation. A 17 1/2” pilot hole was\r\ndrilled from 455 m to 995 m to check for shallow gas before opening up to 26”.\r\nNo shallow gas was seen. Some fishing jobs were required during logging and\r\ntesting, otherwise operations proceeded without significant problems. The well\r\nwas drilled with spud mud down to 455 m, with gel mud from 455 m to 995 m, with\r\ngypsum/polymer mud from 995 m to 2562 m, and with gel mud from 2562 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 34/7-7 penetrated top reservoir at\r\n2561.1 m. The OWC was defined at 2615 m in the Statfjord Group. The average log\r\nporosity in the oil zone is 26.2%, the net/gross is 0.37, and the average water\r\nsaturation is 26.2%. Weak oil shows were seen from around 2140 m in sandstone\r\nand siltstone from early Campanian in the Shetland Group (top Kyrre Formation)\r\nand down to to the top Dunlin Group at 2455 m. Through the Dunlin Group down to\r\nthe top Statfjord reservoir at 2561 m, the shows became stronger. Below the OWC,\r\na sandstone interval at the bottom of the Statfjord (2640 - 2644 m) had good\r\noil shows. Going into the Upper Lunde, the shows disappear.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNineteen cores were cut and recovered during\r\ndrilling of the well. Core 1 to 8 were","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"516","properties":{"OBJECTID":516,"wlbNpdidWellbore":841,"wlbName":"33/12-3","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 33/12-3 was drilled on the Statfjord\r\nstructure in the Tampen Spur area. It was designed to test the erosional\r\nescarpment on the east flank of the structure for possible trapping of\r\nhydrocarbons in an area downfaulted to the Statfjord Field pay section to the\r\nwest. Primary objectives of the well were the Early Jurassic Statfjord Group\r\nsands and possible Middle Jurassic Brent Formation sands.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 33/12-3 was spudded with\r\nthe semi-submersible installation Nordskald on 23 April 1975 and drilled to 1725\r\nm in the Paleocene Balder Formation. At this depth irreparable damage to the\r\nwellhead led to the decision to abandon the well. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo cores were cut and no wire line fluid\r\nsamples were taken.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was permanently abandoned on 16\r\nMay 1975 as junk well. The rig was moved 30 m and replacement well 33/12-4 was\r\ninitiated.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eTesting\u003c/span\u003e\u003c/b\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo drill stem test was performed. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"517","properties":{"OBJECTID":517,"wlbNpdidWellbore":849,"wlbName":"30/6-17 R","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 30/6-17 was drilled on the Alpha\r\nstructure on the western side of the Oseberg Field in the northern North Sea.\r\nThe structure is a tilted and rotated fault block with a Jurassic sequence\r\ndipping towards the east. The main objective was to prove hydrocarbons in the\r\nStatfjord Formation. Prognosed depth was 200 m into the Statfjord Formation\r\nwith TD at ca 2682 m. Well 30/6-17 was drilled by Vildkat Explorer to a depth\r\nof 615 m where it was temporary abandoned due to technical problems. The\r\nre-entry 30/6-17 R was made to fulfil the original objectives.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 30/6-17 was re-entered with\r\nthe semi-submersible installation Treasure Hunter on 14 August 1985 and drilled\r\nto TD at 2650 m in the Early Jurassic Statfjord Formation. The well was drilled\r\nwithout significant technical problems, but about one third of the time was\r\ncounted as downtime. The main contribution to the excessive downtime was waiting on\r\nweather. The well was drilled with KCl/polymer mud from 615 m to 2409 m and\r\nwith NaCl/polymer mud from 2409 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eOil shows were recorded on limestone and\r\ndolomite stringers in the Tertiary and Late Cretaceous, beginning at 1650 m and\r\nall the way down to near BCU at 2290 m. These oil shows were most frequent, and\r\nstrongest, in the interval 1750 to 1810 m in the lower part of the Tertiary\r\nHordaland Group. Two gas bearing sandstones units, possibly reworked Brent\r\nGroup, were found at the BCU (2296 - 2300 m and 2303 - 2308 m). \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe prognosed target for the 30/6-17 well\r\nwas the Statfjord Formation. The well was, however, drilled ca 600 m east of\r\nthe proposed location at a structurally down flank position. At this position\r\nalso the Cook Formation was p","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"518","properties":{"OBJECTID":518,"wlbNpdidWellbore":852,"wlbName":"6506/12-5","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 6506/12-5 was the third well drilled\r\non the Smørbukk Sør Discovery (Beta-structure) in block 6506/12, Haltenbanken\r\narea. The well was designed to appraise the hydrocarbon potential and define\r\nthe hydrocarbon-water contacts. Primary target was Middle and Early Jurassic\r\nsandstone. The Fangst Group siltstone member was expected to be sealing at this\r\ndepth. The well would also test if intervals within the Ror and Tilje\r\nformations also could be sealing rocks. Secondary target was the Late\r\nCretaceous Lysing Formation of the Cromer Knoll Group. \u003c/p\u003e\r\n\r\n\u003cp\u003ePrognosed TD was in the Åre formation at\r\n4559 m RKB.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eAppraisal well 6506/12-5 was spudded with\r\nthe semi-submersible installation Dyvi Delta on 17 October 1985 and drilled to TD at 4587 m in the Early Jurassic Åre Formation. The well was drilled with\r\nless than 2.5 deg deviation down to 4235 m. There were minor incidents with a\r\nfailed anchor and lost circulation in the top hole. A poorly cemented 9\r\n5/8" casing required 116 hours amendment before normal drilling could\r\ncommence. The well was drilled with spud mud down to 393 m. From here a pilot\r\nhole was drilled to 1080 m using gypsum/polymer mud, and then opened up using\r\nspud mud. Further drilling was with gypsum/polymer mud from 1080 m to 3519 m,\r\nand with gel/lignite/lignosulphonate from 3519 m to TD. Shallow gas was not\r\nencountered.\u003c/p\u003e\r\n\r\n\u003cp\u003eSecondary target Lysing Formation came in\r\nat 3157 m and primary target Garn Formation at 3948 m. Hydrocarbons were\r\nencountered in both. An OWC was found in the Lysing Formation at 3178.2 m, and\r\nanother OWC in the Garn Formation at 4010.5 m. The Not Formation as well as top\r\nof the Garn Formation was found to be sealing in this well.\u003c/p\u003e\r\n\r\n\u003cp\u003eCores were cut in the Upper Cromer Knoll\r\nLysing Sands and throughout most of the interval from the lower part of the\r\nViking Group at 3910 m down to 4362 m in the Tilje Formation. A total of 429.43\r\nm was recovered in 27 cores. Core n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"519","properties":{"OBJECTID":519,"wlbNpdidWellbore":853,"wlbName":"6507/7-4","wlbHistory":"\r\n\r\n\r\n\u003ch2\u003e\u003cspan lang=EN-GB\u003eWellbore history \u003c/span\u003e\u003c/h2\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 6507/7-4 was drilled in\r\nthe northern part of the Haltenbanken area, some 190 km west of the Norwegian\r\ncoast. It was drilled to evaluate the "B" prospect in the intensely\r\nfaulted zone that lies at the intersection of the Nordland Ridge in the\r\nnortheast and the Halten Terrace in the south. The prospect was in a southward\r\nplunging horst block formed by a Late Jurassic tensional fault system. Well\r\n6507/7-4 was drilled in a down dip position relative to discovery well 6507/7-2\r\nand the prime objective was to establish the oil/water contact in sandstones of\r\nthe Middle Jurassic Tomma Formation.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 6507/7-4 was spudded with the\r\nsemi-submersible installation Nortrym on 6 November 1985 and drilled to TD at\r\n2850 m in the Early Jurassic Tilje Formation. Due to adverse weather conditions\r\nin the first week of operations spudding of the well was made difficult, and 4.5\r\ndays were lost as WOW in this phase. Swelling clays (gumbo) caused some problems\r\nin the 17 1/2" section. The upper part of the core barrel in core no 3\r\nruptured, unfortunately exactly in the section around OWC. Otherwise operations\r\nproceeded without significant problems. The well was drilled with sea water and\r\ngel sweeps down to 1021 m and with gypsum/polymer mud from 1021 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe Tomma Formation sandstones (Garn\r\nFormation) was prognosed at 2455 m, and encountered at 2449 m. The Garn\r\nFormation was found oil bearing. Oil shows were observed on core no 1 from\r\n2444.5 m (driller's depth) down to 2490.7 m. It was described as a uniform\r\nstrong yellow show with even white cut down to 2463 m when the show became m","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"520","properties":{"OBJECTID":520,"wlbNpdidWellbore":854,"wlbName":"34/8-1","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 34/8-1 was\r\ndrilled on the main prospect \"A\" in the block. A main rotated fault\r\nblock flanking the Viking Graben defines the prospect. The closure of the\r\nprospect was mainly dependant upon a sealing fault separating the prospect from\r\nthe structurally higher Gullfaks area. The main objectives of the well were to\r\nprove possible hydrocarbon accumulations in the structurally and\r\nstratigraphically highest reservoir zone (the Brent Group) in an optimal\r\nposition, to verify the interpretation regarding the stratigraphic and\r\nstructural evolution, and to drill in a position that tested both the\r\nstructural closure and the sealing fault on the \"A\" prospect. \u003c/p\u003e\r\n\r\n\u003cp\u003eSecondary objectives\r\nof the well were to test the hydrocarbon potential, the stratigraphy and the\r\nreservoir quality in the Cook, Statfjord, and upper Lunde Formations; to drill\r\nin a position where the Brent Group showed no or minor erosion; and to drill in\r\na position which left small quantities of hydrocarbons untested up dip in the Brent\r\nGroup. The prognosed depth was 3750 m, ca 100 m into sands of the upper Lunde\r\nFormation.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 34/8-1\r\nwas spudded with the semi-submersible installation \"Treasure Scout\"\r\n11 November 1985 and drilled to a total depth of 3610 m in the Triassic Lunde\r\nFormation. Certain problems were experienced in the beginning, and the well had\r\nto be re-spudded. After this drilling proceeded without significant problems.\r\nThe well was drilled with sea water and hi-vis pills down to 925 m and with KCl\r\npolymer mud from 925 m to TD. The well penetrated a near complete Brent Group.\r\nThe reservoir top came in at 2767 m, approx. 80 a higher than prognosed. Logs\r\nand RFT data show that it is a probability of gas down to 2854 and the\r\noil/water contact is at 2864 m. Thirteen cores were cut in the well, 10 cores\r\nin the Brent Group, one in the Cook Formation, and one in the Lunde Formation.\r\nTwo sets of segregated RFT samples were retrieved from 2","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"521","properties":{"OBJECTID":521,"wlbNpdidWellbore":855,"wlbName":"25/2-10 S","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 25/2-10 S was\r\ndesigned to drill the Gamma Structure, one of the Frigg satellites, east of the\r\nEast Frigg Beta Structure. The primary objective of the well was to test\r\nwhether the gamma structure is an eastward extension of the East Frigg Beta\r\nstructure. The main target was the Lower Eocene Frigg Formation; secondary\r\ntargets were the Balder and Ekofisk Formations. In addition a possible gas\r\naccumulation was expected in a thin sand body of late Oligocene age. \u003c/p\u003e\r\n\r\n\u003cp\u003eShallow gas indications\r\nat 256 m MSL, and a disturbed zone on the seismic from seabed to the Frigg\r\nFormation demanded a deviated well in order to reach the Frigg Formation at its\r\nhighest structural position.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well\r\n25/2-10 S was spudded 2 December 1985 by Sonat Offshore A/S semi-submersible\r\nrig Henry Goodrich. The well terminated in Limestone of the Early Paleocene Ekofisk\r\nFormation at a depth of 2967 m (2643 m TVD RKB).\u003c/p\u003e\r\n\r\n\u003cp\u003eDue to shallow gas\r\nindication on the chosen locality, the well was spudded 1100 m north and 200 m\r\neast of the TD position. Drilling proceeded without significant problems down\r\nto 1049 m here mud was lost. \u003c/p\u003e\r\n\r\n\u003cp\u003eAn Oligocene sand, now re-dataed to be of Lower Miocene age, was\r\nconfirmed in the interval 1115 m to 1148.5 m (1006.5 m to 1031 m TVD RKB) with\r\ngas from top sand at 1115 m down to a GOW at 1136.5 m (1006.5 m to 1022.5 m TVD\r\nRKB). From 1095 m to 1150 m (992 m to 1030 m TVD RKB) strong yellowish green to\r\nyellow ocher direct fluorescence and milky yellow cut were observed on cuttings\r\nand SWC. Pressure measurements suggest an oil gradient of ca 0.72 g/cc below\r\nthe gas with a tentative OWC at 1162 m (1041.5 m TVD RKB). Top Frigg Formation\r\ncame in at 2230 m (1943 m TVD RKB) with minor amounts of oil and gas. The GOC\r\nin the Frigg reservoir was found at 2243.6 m (1956 m TVD RKB) and the OWC at 2259.6\r\nm (1971 m TVD RKB). Brown oil staining was reported on the cores from 2243.5 m\r\nto 2257 m. In the Frigg Forma","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"522","properties":{"OBJECTID":522,"wlbNpdidWellbore":856,"wlbName":"7/11-9","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 7/11-9 is located ca 5.5 km from the\r\n  UK border, North of the Cod and Mime Fields on the Cod Terrace. It was\r\ndesigned to test the sedimentary sequences that were seismically correlateable\r\nwith Ula sands in the 7/11-5 Mime Discovery. The closure of prospect was\r\ndependent on pinch-out of the Ula sands and sealing Triassic rocks over the\r\nfaults to the east and west. Prognosed top of the Ula sands was at 4119 m, and\r\nthe thickness 90 m. Prognosed TD was at 4260 m in Triassic rocks. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 7/11-9 was spudded with the\r\nsemi-submersible installation Byford Dolphin on 26 November 1985 and drilled to\r\nTD at 4271 m in the Triassic Smith Bank Formation. The well was drilled with\r\nseawater and hi-vis pills down to 723 m and with KCl polymer mud from 723 m to\r\n3947 m. Due to stuck drill pipe at 3706 m pills with diesel/Imco Spot/Pipelax\r\nwas spotted. A total of six days were spent freeing the pipe and pulling out of\r\nhole before drilling could commence. The 8 3/8" section from 3947 m to TD\r\nwas drilled with KCl polymer with additions of Chrome lignite starting at 4084\r\nm.\u003c/p\u003e\r\n\r\n\u003cp\u003eTop limestone came in at 3162 m, and the\r\nlimestone continued down to top Rødby Formation at 3899 m. Top Jurassic was\r\nencountered at 4027 m. Grey/brownish siltstone of the Farsund Formation was\r\nencountered at 4093 m. The Ula Formation sand came in at 4168.5 m, and three\r\ncores were cut in the interval 4165- 4209.7 m. The cores indicated a 14 m\r\ncolumn of shows all through the Ula sands down to top Triassic rocks at 4182.5\r\nm. RFT-tests were run and showed very low permeability, which was confirmed by\r\na DST-test. No shows were reported from above or below the Ula Formation. One\r\nRFT sample was recovered from 4181 m. The Horner corrected temperature from 5\r\nhighly consistent wire line BHT's at TD gave a temperature of 170 deg C. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 9\r\nMarch 1986 as a dry well.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eOne DST-test","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"523","properties":{"OBJECTID":523,"wlbNpdidWellbore":858,"wlbName":"34/10-26","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 34/10-26 was drilled to test\r\npossible shallow gas accumulation in sandstones at the location for the\r\nGullfaks C platform. The targets were several sand layers of Pliocene age. Gas had\r\nbeen indicated on seismic anomalies and logs from other wells in the same\r\nfield.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 34/10 was spudded with the\r\nsemi-submersible installation Deepsea Bergen on 18 October 1985 and drilled to\r\nTD at 600 m in Pliocene sediments in the Nordland Group. A problem with running\r\nthe 13 3/8" casing caused a day delay, otherwise no significant problem\r\nwas encountered in the operations. The well was drilled with water based mud.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eTop Pliocene was penetrated between 300\r\nand 317 m. A layer of sandy claystone that appeared to contain traces of gas was\r\npenetrated from 343 m to 350 m. Below this level the well penetrated two water\r\nbearing sand layers without any gas at 355.5 m to 356.5 m and 358.5 m to 360 m.\r\n\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo cores were cut and no wire line fluid\r\nsamples were taken. A full set of conventional logs where run. Cuttings samples\r\nwere taken every 5 m from 320 m to TD. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was permanently abandoned on 26\r\nOctober 1985 4.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eTesting\u003c/span\u003e\u003c/b\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo drill stem test was performed.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"524","properties":{"OBJECTID":524,"wlbNpdidWellbore":859,"wlbName":"34/10-10 R","wlbHistory":"\r\n\r\n\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 34/10-10 and the re-entry 34/10-10 R\r\nwas drilled on the Delta structure situated in the Gullfaks Vest area in the north-eastern\r\npart of block 34/10. The primary objective was to test sandstones of Middle\r\nJurassic age. Secondary objectives were sandstones of Early Jurassic and Late\r\nTriassic age. The well was planned to be drilled into Triassic to a total depth\r\nof 2265 m.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eOn 10 July 1980 at 2330 hrs the semi-submersible\r\ninstallation Norskald was transferred from well 15/9-6 to well 34/10-10. After\r\nthe rig had been anchored up on the 34/10-10 location a strike broke out among\r\nthe drilling crew. Due to the strike the operation was one month delayed and\r\nthe well was not spudded until 15 August at 1930 hrs. The 36" hole was\r\ndrilled to 229 m with a 26" bit and a 36" hole opener without\r\ntemporary guide-base. Seawater was used with returns to the sea floor. The hole\r\nwas slugged with high viscosity mud prior to each connection. The riser was run\r\nand the diverter system installed. From 229 to 816 m in the Nordland Group\r\n(Miocene age) the well was drilled first as a 17 1/2" pilot hole and\r\nlogged, then with a 26" hole opener. When disconnecting the marine riser\r\non 21 August, the well started to flow. The rig was quickly moved off location\r\nand out of danger from the gas flow. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well flowed for approximately one and\r\na half hours the morning of the blowout and again for two and a half hours the\r\nsame evening. Periodic subsea observations over the next days, showed continued\r\nflow from the wellhead at a greatly reduced rate with only one brief surface\r\nindication of flow.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eOn 19","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"525","properties":{"OBJECTID":525,"wlbNpdidWellbore":860,"wlbName":"6507/7-5 A","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 6507/7-5 A is located on the\r\nnorthern part of the Halten Terrace off shore Mid Norway and was drilled to\r\nappraise the northern extension of the 6507/7-2 Heidrun Discovery. Well 6507/7-5\r\nA was drilled as a geological sidetrack from the 6507/7-5 well to further\r\nevaluate and appraise the Middle and Lower Jurassic sands in a downthrown fault\r\nblock adjacent to, and NNW of the one tested by the 6507/7-5 well. Prognosed TD\r\nwas at 2721 m MD RKB.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eAppraisal well 6507/7-5 A was spudded the\r\nsemi-submersible installation Nortrym on 6 March 1986. The well was drilled deviated from 6507/7-5 with kick-off point at 1100 m in the 6507/7-5 well and reached\r\nits TD at 2673 m in the Early Jurassic Tilje Formation. TD location was\r\napproximately 640 m NNW from the top hole location. No shallow gas was recorded\r\nduring drilling. Due to technical problems, prognosed depth was not reached.\r\nThe drill string became differentially stuck during a connection 9 m off\r\nbottom. After 7 days of fishing, the string was backed off, leaving a 387 m\r\nfish in the hole. Hence there were no final logs run on this well. Two days\r\nwere spent waiting for weather. The well was drilled with KCl/polymer mud from\r\nkick-off to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well proved an even longer hiatus in\r\nthis well than in well 6507/7-5: from the Late Cretaceous Turonian to the\r\nMiddle Jurassic Aalenian/Bajocian. Hence, no Late Jurassic sediments were\r\nencountered. The Fangst Group, Garn Formation, came in at 2554.5 m (2420.6 m\r\nTVD RKB) and the Båt Group at 2582.5 m (2445.2 m TVD), with top Tilje Formation\r\nat 2598.0 m (2458.8 m TVD). Analysis of cores indicated good to excellent\r\nporosity and permeability with shows. \u003c/p\u003e\r\n\r\n\u003cp\u003ePoor to moderate shows occurred in\r\nsiltstone and sandstone samples from the Cretaceous between 2300 and down to\r\ntop Jurassic. In the Fangst Group oil shows appeared first at 2560 m, ca 3 m\r\ndown from the top of core no 1 and 5 m below top Garn Formation. A transitiona","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"526","properties":{"OBJECTID":526,"wlbNpdidWellbore":862,"wlbName":"6/3-2","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 6/3-2 was drilled on the gamma\r\nstructure on an early Permian formed fault block, 1.4 km from the Norwegian/UK\r\nmedian line. The primary objective was to test Jurassic/Triassic sandstones at\r\ndifferent levels for possible hydrocarbon accumulations. Secondary objectives\r\nwere to test Cretaceous porous/fractured limestone/chalk and Rotliegend\r\nsandstone. The prognosed TD was 4325 m. The location was chosen due to the\r\nproximity to mature source rocks and oil/gas discoveries in British waters.\r\nSeismic anomalies indicated shallow gas. Due to this the original planned well\r\nlocation was abandoned and a new location was chosen 500 m to the east.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 6/3-2 was spudded with the\r\nsemi-submersible installation ROSS Isle 21 November 1985 and drilled to TD at\r\n4091 m in the Early Permian Rotliegend Formation. Some hole problems were\r\nexperienced in the top of the 12 1/4" hole section. 9 5/8" casing was\r\nset close to the Zechstein formation before drilling the 8 1/2" hole into\r\nthe salt. At 3772 m, an over-pressured zone of dolomite/slate was encountered.\r\nIt was anticipated that one had found a "floating lens" enclosed in\r\nthe evaporites. The well started flowing and pressure was increased to 2.05\r\ng/cc in order to stabilise the well. Because of this a 7" liner had to be\r\nset in the middle of the salt. A 6" hole was drilled to base of the\r\nZechstein Formation and a 5" liner was set in order to be able to reduce\r\nmud weight through the Rotliegend sandstone. The well was drilled with\r\nseawater/hi-vis pills/pre-hydrated bentonite through the top sections to 622 m,\r\nwith gypsum/polymer mud from 622 m to top of the salt at 3400 m, and with\r\nSafemul oil based mud from 3400 m to TD. No indication of shallow gas was\r\nencountered at this location. \u003c/p\u003e\r\n\r\n\u003cp\u003eTop Cretaceous came in at 2511 m. There\r\nwere some shows in the Cretaceous limestone/chalk. However, logs, cores and\r\ncuttings showed that the re","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"527","properties":{"OBJECTID":527,"wlbNpdidWellbore":863,"wlbName":"6406/3-2","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 6406/3-2 is located in the middle of\r\nthe block, west of the Tyrihans North field off shore Mid Norway. The primary\r\nobjective of the well was to find hydrocarbon accumulations of significant size\r\nin the Middle Jurassic. Secondary objectives were hydrocarbon accumulations in\r\nthe Early Jurassic sandstone. The well should also verify the geophysical and\r\nstructural interpretation and improve the geological, paleontological and\r\ngeochemical understanding of the area. Total depth was to be in rocks of\r\nTriassic age or 4000 m in order to satisfy the licence commitment.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 6406/3-2 was spudded with the\r\nsemi-submersible installation West Vanguard on 28 June 1986 and drilled to TD\r\nat 4523 m in the Early Jurassic Åre Formation. The well was drilled practically\r\nvertical down to the deepest survey point at 4261 m (4260 m TVD). In the\r\ntesting phase 543.5 hrs were spent on fishing to get the cement stinger loose.\r\nThe well was drilled with spud mud down to 965 m, with gypsum/polymer mud from\r\n965 m to 2301 m, with gypsum lignosulphonate mud from 2301 m to 3930 m, and\r\nwith lignosulphonate mud from 3930 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe Middle Jurassic sandstones (Garn\r\nFormation) were penetrated at 3930 m and were found to be HC-bearing. The oil contact,\r\nprobably and oil-down-to contact, was found from geochemical methods at\r\napproximately 4030 m. The logs indicated that the oil/water contact was at 4335\r\nm. Oil shows were recorded in several intervals below this depth throughout\r\ndown to TD. RFT data indicated that both Ile and Ti1je Formations were\r\nimpermeable. \u003c/p\u003e\r\n\r\n\u003cp\u003eA total of 285 m core was recovered in 17\r\ncores from the Garn, Not, Ile, Ror, and Tilje formations. No fluid samples were\r\ntaken on wire line.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 22\r\nNovember 1986 as an oil discovery.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eTwo drill stem tests were performed in\r\nthe well. DST 1 tested the interval 4302 - 4336 m in the Tilje Formati","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"528","properties":{"OBJECTID":528,"wlbNpdidWellbore":867,"wlbName":"34/10-27","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 34/10-27 was drilled on the Gullfaks\r\nField to investigate and drain possible shallow gas sands between 342 to 347 m at\r\nthe platform A location on the Gullfaks Field. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 34/10-27 was spudded with the\r\nsemi-submersible installation West Venture on 2 December 1985 and drilled to TD\r\nat 482 m in Pliocene sediments in the Nordland Group. No significant problem\r\nwas encountered in the operations. The well was drilled with water based mud.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eTop Pliocene was encountered at 290 m. Electric\r\nlogs through the 12 1/4" section showed only 1 - 1.5 m of possible shallow\r\ngas sand between 345.5 and 347.1 m. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo cores were cut. The RFT tool was run\r\nin the gas sand for pressure points but no fluid samples were taken. Cuttings\r\nsamples were taken every 5 m from 270 m to TD. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was suspended on 14 December\r\n1985.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eTesting\u003c/span\u003e\u003c/b\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eDue to very thin gas sand no drill stem\r\ntest was performed.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"529","properties":{"OBJECTID":529,"wlbNpdidWellbore":871,"wlbName":"6407/9-6","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 6407/9-6 was drilled on the Draugen\r\nField in the Haltenbanken area off shore Mid Norway. The target was the Rogn\r\nSandstone Formation of the Late Jurassic. The objectives were to identify the\r\nwestern edge of the Rogn\u003c/p\u003e\r\n\r\n\u003cp\u003eFormation, to establish the reservoir\r\nproperties and development of the basal shale, to evaluate the water injection\r\npotential in oil-bearing sand, and to calibrate the seismic velocity.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eAppraisal well 6407/9-6 was spudded with\r\nthe semi-submersible installation Borgny Dolphin 2 January 1986 and drilled to\r\nTD at 1800 m in the Early Jurassic Ror Formation. Drilling proceeded without\r\nsignificant problems. The well was drilled with seawater and bentonite down\r\nto807 m, with KCl/polymer mud from 807 m to 1603 m, and with chalk mud from\r\n1603 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe Rogn Formation was encountered\r\noil-bearing from the top at 1642.5 m (1617.5 m SS) down to the base at 1660 m\r\n(1633.5 m SS). Average reservoir quality over this 17.5 m interval was very\r\ngood, with calculated hydrocarbon saturation of 79 % and an average porosity of\r\n31 %. Core permeabilities in the oil-bearing interval typically ranged between\r\n1 and 10 Darcy. The underlying Fangst Group was interpreted as fully water\r\nbearing below 1671 m (1646 m SS), however low hydrocarbon saturations were\r\ncalculated in the interval 1662 m to 1671 m (1637 - 1646 m SS). These were\r\nconfirmed by the observed fluorescence in the cores over this interval and by\r\nDean-Stark fluid saturation measurements.\u003c/p\u003e\r\n\r\n\u003cp\u003eFour cores were cut in the interval 1646\r\n- 1690.2 m. An FMT survey gave the same reservoir oil and water gradients as in\r\nthe other wells on Draugen, and it was found that the Rogn Formation and the\r\nFangst Group belong to the same pressure regime. One FMT fluid sample was taken\r\nat 1652.5 m in the Rogn Formation. After the well was plugged an intermittent\r\nstream of gas bubbles was observed leaking from the wellhead. Analysis of a\r\nsample of the gas s","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"530","properties":{"OBJECTID":530,"wlbNpdidWellbore":872,"wlbName":"34/10-28","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 34/10-28 was drilled on the fourth\r\nwell drilled on Gullfaks South. It was drilled in the north-eastern part of the\r\nAlpha structure, and the primary objectives were to test for hydrocarbons in\r\nthe Middle Jurassic Brent Group and the Early Jurassic Statfjord Formation. The\r\nEarly Jurassic Cook Formation, water bearing in the other wells on the Gullfaks\r\nSouth, was a secondary objective. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 34/10-28 was spudded with\r\nthe semi-submersible installation Dyvi Stena on 2 January 1986. When running\r\nthe BOP, after having set the 20" casing, the guide posts were damaged and\r\nthe well was abandoned with TD at 528 m in Pliocene sediments in the Nordland\r\nGroup. The well was drilled with water based mud.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eTop Pliocene was encountered at 290 m. Shallow\r\ngas was found in a sand at 332 - 339 m. Otherwise the drilled section contained\r\nclay and only minor sand stringers.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo cores were cut and no fluid samples\r\nwere taken. Only MWD logs were run. Cuttings samples were taken every 10 m from\r\n260 m to TD. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was permanently abandoned on 16\r\nJanuary 1986.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eTesting\u003c/span\u003e\u003c/b\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo drill stem test was performed.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"531","properties":{"OBJECTID":531,"wlbNpdidWellbore":874,"wlbName":"7120/1-1 R","wlbHistory":"\r\n\r\n\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 7120/1-1 was drilled on the Alpha\r\nstructure in the north of block 7120/1. The primary objective of the well was\r\nto test Palaeozoic carbonates and elastics in a partly fault-bounded/truncated\r\ndip closure on the western flank of the Loppa High. Potential Early Triassic\r\nsandstones in a low relief dip closure were a secondary objective.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 7120/1-1 was spudded on 16 August\r\nwith the semi-submersible installation "Borgny Dolphin" and drilled\r\nto 2569 m where it was suspended on 15 November due to NPD drilling regulations\r\nduring winter season. On 2 December permission was granted to continue\r\noperations and drilling continued to 2610 m. On 26 December the well was again\r\nsuspended at the request of the Norwegian Petroleum Directorate because of\r\nsafety considerations in adverse weather conditions. The well was re-entered on\r\n13 March 1986 and drilled to a TD of 4003 m in basement rocks. The well was\r\ndrilled with seawater and bentonite hi-vis pills down to 485 m. From there to TD\r\ngypsum/polymer mud was used with various "Lost Circulation Material"\r\npills to cure mud losses. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well encountered weak hydrocarbon\r\nshows from 800 m down to 2200 m\u00A0 and oil shows in Late Permian carbonates\r\n(Tempelfjorden Group, Ørret Formation).\u00A0 No intervals of significant reservoir\r\npotential were recognized from logs or described from cuttings in the Tertiary\r\nor Triassic sections. Below this sequence, three main Permian carbonate units\r\nwere identified from logs and cuttings description. A porosity range of 5-10%\r\nfor the limestone sequence between 2415 and 2461 m has been derived from log\r\nevaluation. In the basal part of this interval, a black shale was detected with\r\na gas peak of 13% total gas. The lower limestone in","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"532","properties":{"OBJECTID":532,"wlbNpdidWellbore":875,"wlbName":"34/4-6","wlbHistory":"\r\n\r\n\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 34/4-6 was drilled in the northern\r\npart of the Snorre Field. The main objectives were to test the northern outline\r\nof the field and to confirm the oil/water-contact and reservoir characteristics\r\nof the Upper Lunde Formation. The stratigraphy and reservoir characteristics of\r\nthe Middle and Lower Lunde together with the Lomvi Formations were secondary\r\nobjectives. Prognosed depth was at 3236 m in Triassic rocks. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 34/4-6 was spudded with\r\nthe semi-submersible installation Vinni on 31 December 1995 and drilled to TD\r\nat 3282 m in the Late Triassic Teist Formation. The 26" section was\r\nhampered by bad weather and large parts of the period from the evening of 9\r\nJanuary up to 18 January was spent as WOW. When reaching 740 m the bad weather\r\nalso made it necessary to disconnect the riser from the well head. Technical\r\nproblems when attempting to re-latch the pin connector back on to the well head\r\nresulted in the remaining section down to TD at 920 m in the 26" section being\r\ndrilled with no returns to the surface. The well was drilled with spud mud down\r\nto 530 m, with gel mud from 530 m to 920 m, with gypsum/polymer mud from 920 m\r\nto 2345 m, and with gel mud from 2345 m to TD. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eApart from the sandy Utsira Formation of\r\nLate - Middle Miocene to Pliocene age (1127.5 - 1239 m) and a sandstone unit\r\nwithin the Hordaland Group of Early Oligocene age (1358.5 - 1387 m), the upper\r\nsection down to the Base Cretaceous Unconformity proved mainly claystones. No\r\nJurassic rocks were encountered in the well. The Triassic Hegre Group consists\r\nof sandstones with minor shales and siltstones down to TD of the well. The target\r\nhorizon, the Upper Lu","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"533","properties":{"OBJECTID":533,"wlbNpdidWellbore":877,"wlbName":"34/10-30","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\u003cp\u003eWell 34/10-30 was the fifth well drilled\r\non Gullfaks Sør. The well was the "continuation" of the junked well\r\n34/10-28, which was plugged and abandoned at 528 m. Well 34/10-30 was drilled\r\non the Alpha structure, and designed to test for hydrocarbon accumulations in\r\nthe North East part of the structure. The main objectives were the Brent and\r\nStatfjord sandstones. The Lower Jurassic Cook sandstone, which had been water\r\nbearing in the other Gullfaks Sør wells, was considered a secondary objective,\r\nas was the penetration of the oil/water contact. Prognosed depth was 3435 m.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations\u003c/b\u003e\u003c/p\u003e\r\n\u003cp\u003eAppraisal well 34/10-30 was spudded with\r\nthe semi-submersible installation Dyvi Stena on 16 January 1986 and drilled to\r\nTD at 3785 m in the Triassic Lunde Formation. Drilling proceeded without\r\nsignificant problems, but 20" casing was set early due to shallow gas in\r\nthe interval 332-340 m. The well was drilled with spud mud down to 232 m, with\r\nPAC/polymer mud from 232 m to 325 m, with gypsum / PAC mud from 325 m to 1898\r\nm, with gypsum/PAC/"Borewell" mud from 1898 m to 2845 m, and with\r\nLignite/"Borewell" mud from 2845 m to TD. \u003c/p\u003e\r\n\u003cp\u003eA four-meter thick Brent sandstone was\r\nencountered at 2941 m. The sandstone showed a milky white to pale yellow\r\nfluorescence with a slow white streaming cut and a C1/C2 mud gas ratio that\r\nindicate a gas bearing formation. The Cook Formation was dry. The top of the\r\nStatfjord Formation was at 3120 m, approximately 100 m higher than prognosed.\r\nThe formation was all filled with oil and gas and had a gas-oil contact at\r\n3251.6 m. The Lunde Formation was reached at 3375 m. The formation was oil\r\nbearing with no defined oil-water contact. The oil/water contact was expected\r\nat 3395 m. This was not the case and drilling of a 6" section thus commenced\r\npast the prognosed depth. The oil water contact was difficult to define, but\r\nthere is reason to believe it to be at approximately 3712 m. Twenty-two cores\r\nwe","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"534","properties":{"OBJECTID":534,"wlbNpdidWellbore":878,"wlbName":"34/7-8","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 34/7-8 was drilled on the\r\n"C" structure south of the Snorre field area on Tampen Spur in the Northern North Sea. The Late Triassic - Early Jurassic reservoirs of the structure are\r\ntilted fault blocks dipping in a generally north westerly direction. The\r\n"C" structure is defined by a major west bounding fault with throws\r\nup to 350 m in the northwest, diminishing to 20 m at the southern end. The main\r\nobjectives of the well were to test the quality and thickness of the Statfjord\r\nFormation and the Upper Lunde Formation. Further objectives were to test the\r\nfluid content of the structure and sealing effect of the "C" horst\r\nfault.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 34/7-8 was spudded with the semi-submersible\r\ninstallation Treasure Saga on 5 February 1986 and drilled to TD at 2766 m in\r\nthe Late Triassic Lunde Formation. Problems with tight hole were experienced\r\nthrough several zones in the 17 1/2" section. At 1642 m the pipe stuck and\r\nhad to be worked free. During plug and abandon operation of the combined cut\r\nand pull tool caused problems. After several attempts of cutting, the string\r\nparted in the section of drill collars. Fifty-seven m of drill collar, cut and\r\npull tool, wellhead with casing strings, TGB and PGB were left on the seabed.\r\nSeabed clean-up operations were carried out in June 1986, after abandonment.\r\nThe well was drilled with spud mud down to 439 m, with gel mud from 439 m to\r\n870 m, with gypsum/polymer mud from 870 m to 2280 m, and with gel mud from 2280\r\nm to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eApart from the sandy Utsira Formation of\r\nLate Oligocene - Pliocene age, an Early Oligocene (1265 - 1350 m) and a Middle -\r\nLate Eocene (1445 - 1465 m) sandstone unit within the Hordaland Group, the\r\nTertiary and Cretaceous proved mainly claystones. The Jurassic consists of\r\nreworked sandstone, a claystone rich Dunlin Group and alternating sandstones\r\nand claystones in the Statfjord Formation. The Triassic proved sandstones\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"535","properties":{"OBJECTID":535,"wlbNpdidWellbore":879,"wlbName":"6507/7-5","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 6507/7-5 is located on the northern\r\npart of the Halten Terrace off shore Mid Norway and was drilled to appraise the\r\nnorthern extension of the 6507/7-2 Heidrun Discovery. The primary objective was\r\nMiddle and Lower Jurassic sands in a downthrown fault block located NNW of the\r\n6507/7-2 well. Prognosed top Jurassic was at 2308 m.\u003c/p\u003e\r\n\r\n\u003cp\u003eSecondary objective was the Båt Group at\r\nan expected depth of 2394 m. Based on site survey, shallow gas could appear at 512,\r\n570, 618, 746, and 799 m. Prognosed TD was 2675 m.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eAppraisal well 6507/7-5 was spudded with\r\nthe semi-submersible installation Nortrym on 16 January 1986 and drilled to TD at 2660 in the Early Jurassic Tilje Formation. The 26" hole section\r\nwas drilled without marine riser to 1040 m, first as a 17 1/2" pilot hole\r\nwith MWD logging, then opening up to 26". No shallow gas was recorded. The\r\nMWD quality was good, so no electric logging was performed in this section.\r\nSince no riser was used, all returns were to seafloor down to 1040 m. No\r\nsignificant problems were encountered during operations. The well was drilled\r\nwith seawater and pre-hydrated gel down to 1040 m and with KCl/polymer mud from\r\n1040 m to TD. \u003c/p\u003e\r\n\r\n\u003cp\u003eNo sandstone of importance was\r\nencountered above the Middle Jurassic. A hiatus from Late Cretaceous Turonian\r\nto Late Jurassic Oxfordian/Kimmeridgian was observed at 2310 m. Sandstones of\r\nthe Fangst Group were encountered at 2353 to 2424 m. Analysis of cores and logs\r\nindicated good to excellent porosity and permeability in these sandstones, with\r\nthe best reservoir properties towards the top, in the Garn Formation. \u003c/p\u003e\r\n\r\n\u003cp\u003ePoor oil shows were observed in sandstone\r\nlenses in core no 1 from the Shetland Group (2255.0 - 2282.5 m), which\r\nconsisted mainly of claystones. Visible shows of uniform light brown oil were\r\nobserved on cores from top of the Garn Formation down to 2400 m. Below this\r\ndepth the shows were occasionally more patchy, un","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"536","properties":{"OBJECTID":536,"wlbNpdidWellbore":881,"wlbName":"7121/7-2","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 7121/7-2 was drilled on the Beta\r\nstructure on Tromsøflaket, 3.4 km south of well 7121/7-1. It was designed to\r\ntest the hydrocarbon potential in Middle to Lower Jurassic sandstones. Planned\r\ntotal depth was in rocks of Triassic age.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 7121/7-2 was spudded with\r\nthe semi-submersible installation Ross Isle on 7 July 1986 and drilled to TD at\r\n2156 m in the Late Triassic Fruholmen Formation. At 871 m in the 17 1/2"\r\nsection the string parted and 9.5 hours was spent fishing to retrieve the lost\r\nequipment. At 1698 m, TD in the 17 1/2" section a H2S alarm occurred with\r\n28 ppm H2S in the mud gas.\u00A0 The problem was cured by placing spud mud with a\r\nconcentration of 15 kg/m3 of ZnCO3 behind 13-3/8" casing to prevent H2S\r\ngrowing in mud. The well was drilled with spud mud down to 667 m and with\r\npolymer/"Shale-Trol" mud from 667 m to TD. The well acted as a pilot\r\nwell for testing this mud on Tromsøflaket. The main reason for using this mud\r\nsystem was that it was expected to stable the hole through sections that from\r\nprevious experience had proven to cause tight-hole problems. The mud performed\r\nbetter than the ordinary gypsum/polymer mud previously used in the area, but\r\ntotal costs were higher and it was thus not considered a success.\u003c/p\u003e\r\n\r\n\u003cp\u003eHydrocarbon bearing Middle Jurassic\r\nsandstones (Stø Formation) were encountered at 1881.5 m. The gas/water contact\r\nin this well was recognized at 1914.4 m, ca 12 m deeper than in the 7120/9-1\r\nAlbatross Discovery. The gas zone, 1881.5 m to 1914.4 m, consists of an\r\ninterbedded silt, shale and very fine sandstone sequence with good reservoir\r\nproperties. Two cores were cut in the Stø Formation over the interval 1903 m to\r\n1939 m, (1889 m to 1935 m, loggers depth). Three FMT samples were collected,\r\none at 1884.5 m and two at 1899 m.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned as a\r\ngas discovery on 12 August 1986.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThe int","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"537","properties":{"OBJECTID":537,"wlbNpdidWellbore":884,"wlbName":"25/5-1","wlbHistory":"\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan class=a1455\u003e\u003cspan lang=EN-US\u003eWell 25/5-1 was drilled\r\non a Jurassic structure straddling the two blocks 25/5 and 25/2. It is located\r\nnear the crest of a westward tilted Jurassic fault block in the northern part\r\nof block 25/5. The northern extension of this structure was drilled in 1977 by\r\nwell 25/2-6 which is located In the southern part of the neighbouring block\r\n25/2, in a down dip position relative to well 25/5-1. Well 25/2-6 was plugged\r\nand abandoned with limited oil shows in sandstones of the Early Jurassic\r\nStatfjord Formation. The main objectives of well 25/5-1 were to test the\r\nhydrocarbon potential of the middle Jurassic Vestland Group sandstones and the\r\nEarly Jurassic Statfjord Formation sandstones up dip of well 25/2-6.\u003c/span\u003e\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan class=a1455\u003e\u003cspan lang=EN-US\u003eWildcat well 25/5-1 was\r\nspudded 12 May 1987 by Norcem semi-submersible rig Nortrym and completed 1\r\nAugust 1987 at a depth of 3430 m in the Triassic Group. Drilling proceeded\r\nwithout significant problems. There was no sign of shallow gas. One core was\r\ncut in the Draupne Formation between 2916 and 2925 m. Top reservoir (Hugin\r\nFormation) was encountered at 2984 m. Five cores were cut between 2990 - 3081 m\r\nin the Hugin and Sleipner formations and into the Drake Formation. The logs\r\nshowed that the whole reservoir section contained oil down to base Sleipner /\r\ntop Drake Formation, which formed a lithological sand / shale contact at 3060\r\nm. RFT pressure measurements indicated an oil/water contact at ca 65 m below\r\nthis level, implying a vertical oil column of 166 m. Due to this the hole was\r\ndecided to be sidetracked to find the oil/water contact in the Sleipner\r\nFormation. Top Statfjord came in at 3232 m, and 3 cores were cut in the\r\ninterval 3235 - 3291 m. There were shows down to 3264 m; below this depth the\r\nsandstones were wate","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"538","properties":{"OBJECTID":538,"wlbNpdidWellbore":887,"wlbName":"34/10-31","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 34/10-31 was drilled on the Gullfaks\r\nField to drain possible shallow gas sands at the platform A location on the Gullfaks\r\nField. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 34/10-31 was spudded with\r\nthe semi-submersible installation West Venture on 8 April 1986 and drilled to\r\nTD at 420 m in Pliocene sediments in the Nordland Group. No significant problem\r\nwas encountered in the operations. The well was drilled with water based mud.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eTop Pliocene was encountered at 295 m. Electric\r\nlogs through the 12 1/4" section proved three shallow gas sand layers at\r\n344 - 346 m, 350 - 352 m, and 384.5 and 385.5 m. Average gas saturation in the\r\nthree sands were estimated to 60%, 15%, and 40%, respectively.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo cores were cut and no fluid samples\r\nwere taken. Cuttings samples were taken every 5 m from 270 m to TD. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was permanently abandoned on 14\r\nDecember 1985.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eTesting\u003c/span\u003e\u003c/b\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eA production test was conducted from the\r\ninterval 344 to 346.5 m. Shallow gas was produced from 17 February up to 4\r\nApril when it was terminated due to an upcoming strike. A total of 2453203 Sm3\r\ngas was produced at an average rate of ca 65000 Sm3 gas/day during the main\r\ndraining flow. The gas gravity was 0.552 - 0.560 (air = 1). The reservoir\r\ntemperature was reported to be 14 deg C.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"539","properties":{"OBJECTID":539,"wlbNpdidWellbore":888,"wlbName":"34/10-27 R","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 34/10-27 R is a re-entry of well\r\n34/10-27. The primary well was drilled on the Gullfaks Field to investigate and\r\ndrain possible shallow gas sands at the platform A location on the Gullfaks\r\nField. It was suspended without testing after detecting a thin shallow gas\r\nsand. The aim of the re-entry was permanent plugging and abandonment.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 34/10 was re-entered on 27 January\r\n1986 with the semi-submersible installation West Venture \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was plugged and permanently\r\nabandoned on 31 January 1986.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eTesting\u003c/span\u003e\u003c/b\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo drill stem test was performed.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"540","properties":{"OBJECTID":540,"wlbNpdidWellbore":889,"wlbName":"34/7-9","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 34/7 9 was drilled on the Snorre\r\nstructure in the northernmost part of the block. The main objective of the well\r\nwas to test the hydrocarbon potential of the upper Lunde Formation in the\r\nSnorre structure. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 34/7-9 was spudded with\r\nthe semi-submersible installation Treasure Saga on 13 April 1986 and drilled to\r\nTD at 3240 m in the Late Triassic Lunde Formation. Minor shallow gas peaks were\r\nobserved from mud gas readings in the pilot hole below the 30" casing at\r\n498 - 500 m. Drilling proceeded without significant problems. The well was\r\ndrilled with spud mud down to 471 m, with gel mud from 471 m to 915 m, with\r\ngypsum/polymer mud from 915 m to 2479 m, and with gel mud from 2479 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 34/7-9 penetrated the reservoir at\r\n2442.5 m, 50 m deeper than prognosed. From FMT pressure points the the oil\r\nwater contact (OWC) was defined in the upper Lunde at 2600 m (2574 m MSL). The\r\naverage log porosity in the oil zone was 25.6%, the net/gross was 0.24, and the\r\naverage water saturation was 30%. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eShows were seen from 2100 to 2315 m in\r\nthe Shetland Group. Below 2315 m the shows disappeared and did not reappear\r\nbefore the upper Lunde reservoir was penetrated at 2442.5 m. Down to a\r\nsandstone/claystone boundary at 2594 m, the sandstones showed a pale brown oil\r\nstain, fair to good odour, 100% - 90% strong, patchy, yellow to light yellow fluorescence,\r\nfast to instant streaming bluish white cut and a pale yellow residue upon\r\nevaporation. Below 2594 m no shows were seen.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eA total of 10 cores were cut and\r\nrecovered during drilling of the well. The cores were taken in the upper Lunde\r\nFormation from ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"541","properties":{"OBJECTID":541,"wlbNpdidWellbore":892,"wlbName":"30/6-20","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 30/6-20 was drilled on the Lambda\r\nstructure west of the Oseberg Field in the North Sea. Lambda, Alpha North,\r\nTheta and Theta South are all rotated fault blocks with the Jurassic sequence\r\ndipping towards the east-northwest. The primary objective was to prove\r\nhydrocarbons in the Statfjord Group up-dip of well 30/6-16 Theta. The Statfjord\r\nGroup is truncated by the base Cretaceous Unconformity to the west, and by\r\nfaults to the south and east. Planned TD was ca 40 m into the Triassic Hegre\r\nGroup, at a depth of ca 3025 m RKB.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 30/6-20 was spudded with the\r\nsemi-submersible installation Treasure Scout on 10 March 1986 and drilled to TD\r\nat 3046 m in the Early Jurassic Statfjord Group. A pilot hole was drilled from\r\n222 m to 620 m due to a shallow gas warning at 363 m. A thin sand with shallow\r\ngas was penetrated at this depth without creating any problem. Drilling\r\nproceeded without significant problems, but was delayed ca 8 days by bad\r\nweather. The well was drilled with sea water and viscous pills down to 620 m\r\nand with KCl/polymer mud from 620 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe Cook Formation came in at 2747 m, and\r\nStatfjord Group at 2937 m. The seismic reflector that was interpreted as top\r\nStatfjord Group proved to be top Cook Formation. This implies that the fault\r\nbounding to the east has a larger throw than first assumed. Both Cook Formation\r\nand Statfjord Group were found water bearing, but with some oil shows in the\r\nCook Formation. RFT data indicated pressure communication between Cook and Statfjord.\r\nThe first oil show in the well was described on claystone at 1990 m in the\r\nBalder Formation. Oil shows in thin limestones and claystones were seen also in\r\nthe Shetland Group. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"542","properties":{"OBJECTID":542,"wlbNpdidWellbore":893,"wlbName":"35/11-2","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eBlock 35/11 is situated at the boundary\r\nbetween the Horda Platform and the Viking Graben just north of the Troll Field\r\nand south of block 35/8 where two gas/condensate discoveries had been made. The\r\nwork obligation for Block 35/11 included three exploration wells to be drilled\r\nto 4000 metres or to Triassic sediments, one of which must test an Early\r\nCretaceous stratigraphic play. The first of these wells, 35/11-1, was drilled\r\nin 1984 to a depth of 3361 m in rocks of Triassic age. The primary objective of\r\nthat well was to assess the hydrocarbon potential of the Middle to Upper\r\nJurassic sands in the "A" structure. No hydrocarbons were present in\r\nany of the objectives although good quality Brent sands were encountered. The second\r\nwell to be drilled on the block was 35/11-2. It was designed primarily to test\r\nan Early Cretaceous stratigraphic play, interpreted seismically as a fan\r\ndevelopment with a 130 km3 closure, and reservoir thickness of 270 m. A\r\nsecondary objective was the "B" structure at Brent level. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 35/11-2 was spudded with the\r\nsemi-submersible rig Treasure Scout on 20 July 1987 and drilled to TD at 4025 m\r\nin Early Jurassic rocks. The hole was drilled to setting depth for 20"\r\ncasing without a riser. MWD was used, but the resistivity unit was destroyed\r\nafter few meters. Conventional logs did not get past 760 m, and while\r\nattempting this; there was an intrusion of formation fluid into the hole. There\r\nwas no sign of shallow gas, and heavier mud was used. The hole was opened to\r\n26" without logging below 760 m. The reason for the problems around 760 m\r\nwas probably washed-out zones. When preparing the setting of 20"casing,\r\nfluid was again flowing into the hole, and the mud weight was increased.\r\nFurther dril","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"543","properties":{"OBJECTID":543,"wlbNpdidWellbore":894,"wlbName":"30/6-17 A","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 30/6-17 A is a sidetrack to well\r\n30/6-17 R on the western side of the Oseberg Field. Well 30/6-17 R did not\r\npenetrate the Statfjord Formation in a high structural position as planned. The\r\nsidetrack was drilled to fulfil the objective. Secondary objectives were to\r\nappraise the Cook Formation discovery and the gas sands around BCU found in\r\n30/6-17 R. Finally, a minifracture test would be conducted to obtain\r\nminimum-horizontal-stress data that could improve drilling efficiency in Eocene\r\nclays in the Oseberg area. Prognosed depth of the well was 3532 m (2690 m TVD),\r\n50 m into the Statfjord Formation.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 30/6-17 was re-entered with the semi-submersible\r\ninstallation Treasure Hunter on 4 February 1986. Sidetrack 30/6-17 A was kicked\r\noff due west from below the 13 3/8" casing, with kick off point at 1633 and\r\ndrilled to TD at 2686 m (2528 m TVD) in the Early Jurassic Statfjord Formation.\r\nDrilling proceeded without significant problems. It was drilled with KCl/polymer\r\nmud from kick off to 2335 m and with NaCl/polymer mud from 2335 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well encountered a gas bearing Cook\r\nFormation while the Statfjord Formation was found water bearing. Hydrocarbon\r\nshows seen in Tertiary and Cretaceous limestones similar to in 30/6-17 R, and also\r\nin a ca 5 meter thick sandstone bed associated with the Base Cretaceous\r\nUnconformity. The Cook Formation (2460 - 2488 m, 2357.5-2379 m TVD) is\r\ndeveloped as an overall coarsening upward sequence. The grain size is fine to\r\nmedium at the upper part, becoming very fine to fine with increasing silt\r\ncontent downwards. The whole of the Cook Formation was found gas bearing with a\r\nnet pay of 27.9 m. No oil/gas contact was thus seen. The average porosity is\r\n24.1% and the average","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"544","properties":{"OBJECTID":544,"wlbNpdidWellbore":895,"wlbName":"2/4-1","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 2/4-1 drilled by Phillips\r\nwas the first well to be drilled in block 2/4 and the thirty-second to be\r\ndrilled on the Norwegian continental shelf altogether without making a\r\ncommercial discovery. The objective of the 2/4-1 well was to test the\r\nhydrocarbon potential of the Tertiary and top Mesozoic.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 2/4-1was spudded with the\r\nsemi-submersible installation Ocean Viking on 21 August 1969 and drilled to TD\r\nat 1662 m in Miocene dolomite\u00A0 (Nordland Group) where it was terminated due to\r\noil kicks and circulation problems. \u003c/p\u003e\r\n\r\n\u003cp\u003eA 200 ml sample of the kick-oil was\r\ncentrifuged from the mud. The probable depth of the sample was reported to be\r\n1646 m to 1661 m. Due to a high content of water and solids still remaining\r\nafter centrifuging, and because the virgin mud itself contained "a small\r\namount of gasoil", an exact characterisation of the native oil could not\r\nbe made. However, the oil had high viscosity, and true boiling point\r\ndistillation indicated that more than 50% of the oil was a heavy residue with\r\nboiling point above 400 deg C. The oil was also reported to have a\r\n"disagreeable odor of oxidised hydrocarbons". No cores were cut and\r\nno wire line logs were run.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was junked and permanently\r\nabandoned on 16 September 1969 as a well with strong oil shows. The original\r\nwell objectives were not fulfilled, and since the oil kick could indicate a\r\ndiscovery a new well (2/4-2) was initiated two days later at a location ca 1 km\r\nsouth of the 2/4-1 well.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was performed\u003c/p\u003e\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"545","properties":{"OBJECTID":545,"wlbNpdidWellbore":896,"wlbName":"7121/1-1 R","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 7121/1-1 was\r\ndrilled on the Loppa High in the northern part of the Tromsøflaket area,\r\noffshore Northern Norway. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe primary\r\nobjective of the 7121/1-1 exploration well was to test the reservoir and\r\nhydrocarbon potential of a possible Early Permian (Artinskian) mounded\r\ncarbonate facies (biohermal build-ups) identified by seismic. Secondary\r\nobjectives were Late Permian carbonates and Early Carboniferous to Devonian\r\nsandstones, Late Carboniferous - Early Permian carbonates, and Triassic\r\nsandstones. Finally, the exploration well was designed to fulfill the license's\r\nobligatory work program which committed the licensees to drill one wildcat well\r\nto test prospects down to rocks of Devonian age or 5000 m, whichever came\r\nfirst. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eExploration well\r\n7121/1-1 was spudded on 10 October 1985 in 369 m water depth with the\r\nsemi-submersible installation "Zapata Ugland". Due to NPD winter\r\nseason regulations drilling was stopped at 916 m. Drilling of well 7121/1-1R\r\ncommenced on 19 March 1986 and reached total depth of 5000 m in Late\r\nCarboniferous sediments of the Ørn Formation. The well was drilled with sea\r\nwater and gel down to 1978 m, and with Sea water / gel / polymer from 1978 m to\r\nTD. Lost Circulation Material was used below 3370 m. Triassic rocks were\r\nencountered at 698 m, unconformably underlying 178 meters of Tertiary claystone\r\nand siltstone. The Triassic sediments (2295 m thick) consisted predominantly of\r\nvery fine clastics with minor interbeds of sandstone, stringers of dolomite and\r\nlimestone and traces of coal.\u003c/p\u003e\r\n\r\n\u003cp\u003eFair to poor\r\nhydrocarbon shows were encountered in some thin and tight sandstones of Late\r\nand Middle Triassic age. The only significant hydrocarbon show was encountered\r\nin a 11.5 m thick sandstone bed, between 1932.0 and 1943.5 m, where 18.7 % gas\r\n(C1 & C4) was measured by the gas detectors. The Paleozoic section (Permian -\r\nLate Carboniferous Ørn Formation) was encountered at 2","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"546","properties":{"OBJECTID":546,"wlbNpdidWellbore":897,"wlbName":"7120/1-1 R2","wlbHistory":"\r\n\r\n\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 7120/1-1 was drilled on the Alpha\r\nstructure in the north of block 7120/1. The primary objective of the well was\r\nto test Palaeozoic carbonates and elastics in a partly fault-bounded/truncated\r\ndip closure on the western flank of the Loppa High. Potential Early Triassic\r\nsandstones in a low relief dip closure were a secondary objective.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 7120/1-1 was spudded on 16 August\r\nwith the semi-submersible installation "Borgny Dolphin" and drilled\r\nto 2569 m where it was suspended on 15 November due to NPD drilling regulations\r\nduring winter season. On 2 December permission was granted to continue\r\noperations and drilling continued to 2610 m. On 26 December the well was again\r\nsuspended at the request of the Norwegian Petroleum Directorate because of\r\nsafety considerations in adverse weather conditions. The well was re-entered on\r\n13 March 1986 and drilled to a TD of 4003 m in basement rocks. The well was\r\ndrilled with seawater and bentonite hi-vis pills down to 485 m. From there to TD\r\ngypsum/polymer mud was used with various "Lost Circulation Material"\r\npills to cure mud losses. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well encountered weak hydrocarbon\r\nshows from 800 m down to 2200 m\u00A0 and oil shows in Late Permian carbonates\r\n(Tempelfjorden Group, Ørret Formation).\u00A0 No intervals of significant reservoir\r\npotential were recognized from logs or described from cuttings in the Tertiary\r\nor Triassic sections. Below this sequence, three main Permian carbonate units\r\nwere identified from logs and cuttings description. A porosity range of 5-10%\r\nfor the limestone sequence between 2415 and 2461 m has been derived from log\r\nevaluation. In the basal part of this interval, a black shale was detected with\r\na gas peak of 13% total gas. The lower limestone in","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"547","properties":{"OBJECTID":547,"wlbNpdidWellbore":898,"wlbName":"25/7-1 S","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 25/7-1 S was drilled in the southern\r\npart of the Viking Graben, close to the UK border. The primary objective was\r\ntest Late Jurassic sands in a down thrown fault block located northwest of the\r\nBalder Field. Secondary objectives were Middle Jurassic sandstones and the\r\nPaleocene Heimdal Formation sands, if developed. Prognosed TD was 4525 m.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 25/7 1S was spudded with the\r\nsemi-submersible installation Nortrym on 14 April 1986 and drilled to TD at 3592\r\nm in Silurian basement. While tripping from 1525 m the pipe became stuck and\r\nthis resulted in a 38 m fish being left in the hole from 1067 to 1105 m. The\r\nkick off to bypass the fish was at 1024 m. The hole was then drilled to 2094 m\r\nbefore becoming stuck at 1930 m during a trip. The drill string was freed again\r\nafter 5 days. Drilling then proceeded to 2477 m at which depth the pipe became\r\nstuck for a further 17 hours. The well was drilled with seawater down to 1024\r\nand with KCl/polymer mud from 1024 m to TD. Two % diesel was added to the mud\r\nbelow 3241 m to alleviate high torque.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe original geological model for the\r\nprospect was wrong. Jurassic - Devonian rocks were not found. A possible\r\nexplanation is that drilling took place along a fault zone. No good hydrocarbon\r\nindications or fluorescence were observed in the well. One sample at 2084 m (Balder\r\nFormation) was described as having an orange/brown medium fluorescence, occasionally\r\nbright, with a fast, strong, cream/white fluorescent cut.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eOne\u003c/span\u003e\u003cspan\r\nlang=EN-US\u003ecore was cut at \u003c/span\u003e\u003cspan lang=EN-GB\u003e3547.0 - 3554.8 m across an\r\nindeterminate, possibly Triassic section overlying basement, and a second at 3589.0\r\n- 3592.0 m in basement roc","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"548","properties":{"OBJECTID":548,"wlbNpdidWellbore":901,"wlbName":"16/10-1","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 16/10-1 was the first well drilled\r\nin block 16/10 operated by Norsk Agip. Among the various structures defined\r\nwithin block 16/10, the one called "Alpha", located in the\r\nsouthwestern area, was selected as the first one to be drill. Main reason for\r\nthis choice was the presence of a deep basin (Witch Ground Graben) to the south\r\nwest of the block, where the Viking Group shales was believed to have generated\r\nhydrocarbons since Cretaceous time. The tectonic evolution of the structure is\r\nprobably of pre-Cretaceous age, well before hydrocarbon generation started.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe purpose of the well was to explore\r\nall main reservoirs down to Triassic. The primary targets were the Jurassic and\r\nTriassic sandstone units, expected at 2850 m and 2980 m, respectively.\r\nPrognosed TD was at 3175 m.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 16/10-1 was spudded 25 May\r\n1986 by Dyvi Offshore A/S semi-submersible rig Dyvi Stena and drilled to TD at\r\n3151 m in the Late Permian Zechstein Group. The well was drilled with Seawater\r\nand hi-vis pills down to 514 m, with KCl/Polymer mud from 524 m to 2565 m, and\r\nwith lignosulphonate mud from 2565 m t TD. Drilling proceeded without any\r\nsignificant problems. Electrical logs were run already in the 26" section\r\nfrom 195 m. No shallow gas was encountered. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe Quaternary/Tertiary sequence, 2280.5\r\nm thick, is represented by Nordland, Hordaland and Rogaland groups and is\r\npredominantly constituted by marine claystones. A 513.5 m Cretaceous section\r\nrepresented by the limestones of the Chalk Group and by the reddish marl and\r\ncalcareous shales of the Cromer Knoll Group was penetrated. It was nearly a\r\ncomplete sequence except for two possible hiatus: the first in the Late\r\nSantonian and the second between the Cenomanian and the Aptian-Albian. The base\r\nCretaceous Unconformity overlies the Late Jurassic shales of the Viking Group\r\n(top at 2794 m), which proved to have a thickness of 211 m. The top of the\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"549","properties":{"OBJECTID":549,"wlbNpdidWellbore":902,"wlbName":"2/11-7","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 2/11-7 was designed to test a Jurassic reservoir half\r\nway between the crest and the mapped closing contour of a fault controlled\r\nstructure up dip from the Danish well Gert-1 in the same structure. The primary\r\nobjective was the middle Jurassic sands, expected to come in at 4696 m. Seismic\r\nanomalies at 320, 350, and 445 m respectively. Prognosed TD was 5025 m.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 2/11-7 was spudded with\r\nWi1h. Wi1helmsen semi-submersible installation Treasure Scout on 16 April 1986\r\nand drilled to TD at 5042 m in Late Jurassic shales of the Haugesund Formation.\r\nThe well was flow checked at 318 m and 445 m, without any indications of gas.\r\nThe well was drilled with seawater and hi-vis pills down to 1016 m, with KCl mud\r\nfrom 1016 m to 3737 m, and with Lignosulfonate mud from 3737 m to TD. Due to\r\nhigh gas readings and subsequent problems with increased mud weight and lost\r\ncirculation up to 14% oil was added to the mud at 3799 m. This mud was\r\nsubsequently circulated out and displaced with new mud, but a level of 1% to 8%\r\noil was recorded in the mud from 3799 m to TD. Due to high formation pressure\r\nand safety problems, drilling was terminated in Late Jurassic shales before\r\nhaving reached the target Middle Jurassic sand.\u003c/p\u003e\r\n\r\n\u003cp\u003eShows were reported from lowermost Chalk\r\nGroup, limestones of the Cromer Knoll Group, and from Upper Jurassic Dolomite\r\nand sandstone stringers. No conventional cores were cut. Thirty sidewall cores\r\nwere attempted from 3801,5 m to 3756 m whereof 10 were recovered. No fluid\r\nsamples were taken. The well was permanently abandoned as a dry well with shows\r\non 6 September 1986. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was performed\u003c/p\u003e\r\n\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"550","properties":{"OBJECTID":550,"wlbNpdidWellbore":904,"wlbName":"29/3-1","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 29/3-1 was\r\ndrilled in an area adjacent to several major hydrocarbon discoveries close to\r\nthe UK-Norway median line. The structure is located in the highest part of a\r\nwesterly tilted fault panel and the closure is provided by fault to the North\r\nEast and South and by structural dips westward.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe objectives of\r\nthe well were to test hydrocarbon potential of the Middle Jurassic Brent\r\nsandstones; and to test the reservoir potential of the Dunlin sands.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 29/3-1\r\nwas spudded 20 may 1986 by Dolphin Services A/S semi-submersible installation\r\nByford Dolphin and completed 15 September 1986 at a depth of 4427 m in the\r\nEarly Jurassic Statfjord Formation. The 17 1/2" hole (756 m to 2252 m) was\r\ndrilled with KCL/polymer fluid. Well section below 13 3/8" casing point\r\n(2252 m) was drilled oil based with Safemul Invert Emulsion mud (80 % base\r\noil). Drilling was delayed due to a destroyed guide block, after that drilling\r\nproceeded without significant problems. The Tarbert Formation was water bearing\r\nwith residual hydrocarbons and minor amounts of gas in the top section. The\r\nlower Ness Formation contained a 150 m hydrocarbon column. The Dunlin Group was\r\nwater bearing. The Statfjord Formation was found tight and water bearing. Two\r\ncores were cut in the Brent sandstones in the interval 3525 m to 3561 m. Five\r\nRFT samples were taken in the Brent Group: 3821.5 m (Ness: oil and water), 3719\r\nm (Ness: oil and gas), 3697.8 m (Ness: oil and gas), 3556.4 m (Tarbert: water\r\nand filtrate), and 3530 m (Tarbert: gas and water). All samples showed\r\nunusually high oil filtrate recovery due to a very deep invasion by the oil\r\nbase mud.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was plugged\r\nand abandoned as a gas and oil discovery.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eFour drillstem tests\r\nwere performed in the Brent Group. \u003c/p\u003e\r\n\r\n\u003cp\u003eDST 1B was performed\r\nin three zones in the Ness Formation over the interval 3802 m to 3822 m. In\r\nthis test no f","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"551","properties":{"OBJECTID":551,"wlbNpdidWellbore":906,"wlbName":"17/11-1","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 17/11-1 was drilled close to the\r\nwestern edge of the Sele High in the North Sea. The original objective to test\r\nthe Tertiary and Mesozoic sequences, was extended to penetrate the Zechstein\r\nsalt and investigate the underlying formations. This latter could not be\r\nreached due to drilling difficulties in the salt.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 17/11-1 was spudded with the\r\njack-up installation Orion on 24 May 1968 and drilled to TD at 3269 m in the\r\nLate Permian Zechstein Group. When logging at 1173 m the logging tool got stuck\r\nin the "gumbo" section and an inflow of 2 - 5 bbl/hr of salt water\r\noccurred. Several of the tools failed to reach the bottom, among these the\r\ngamma-ray/sonic logging tool. Therefore a laterolog is included on the final\r\ncomposite log in the interval 1017-1158 m. The pipe stuck when drilling in\r\npotassium and magnesium salt (carnallite). Efforts to free the pipe by jarring\r\nand spotting Pipelax were unsuccessful. After working the stuck pipe for 19\r\nhours the drill string parted, leaving a bit and junk sub in the hole. An\r\nunsuccessful attempt was made to jar the fish free. It was then decided that\r\nfurther efforts to drill to the base of the salt could not be justified. The\r\nwell was drilled with seawater down to 166 m, a Spersene/XP-20 mud system from\r\n166 m to 2539 m, converting to a salt-saturated mud from 2539 m through salt to\r\nTD.\u003c/p\u003e\r\n\r\n\u003cp\u003eShetland Group chalk (Ekofisk Formation)\r\ncame in at 1020 m. Top Cretaceous is set at 1040 m where Tor and Hod chalks\r\nextend down to 1447 m. Porosities in the chalks were estimated between 15 % to\r\n25%. At 1447 m 63 m of Ran Sandstone Units were penetrated. The remaining Early\r\nCretaceous consisted of mudstones. The Boknfjord Group was encountered at 2083\r\nm, with shales extending down to 2211 m. These shales rest directly on Triassic\r\nsediments. The Skagerrak Formation from 2211 m to 2315 m\r\nconsisted of claystone with sand and siltsone stringers. The sandstone\r\ns","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"552","properties":{"OBJECTID":552,"wlbNpdidWellbore":907,"wlbName":"7121/5-2","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 7121/5-2 is located ca 10 km\r\nnortheast of the Snøhvit Field. The purpose of the well was to test the\r\nhydrocarbon accumulation on the Beta-structure in sandstones of the Early to\r\nMiddle Jurassic Stø-formation.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was spudded with the\r\nsemi-submersible installation Ross Isle on 26 May 1986 and drilled to TD at\r\n2543 m in Late Triassic sediments (Rhaetian age). The well was drilled with\r\nseawater and hi-vis pills down to 850 m, with gypsum/polymer mud from 850 m to\r\n1977 m, and with gypsum/polymer/NaCl mud from 1977 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eHydrocarbon bearing Middle Jurassic\r\nsandstones in the Stø Formation were encountered at 2323 m. The gas-bearing\r\nzone extends from 2323 m to 2346 m. The gas zone is sealed from the underlying\r\noil zone by a 6 m thick dense shale layer, which prevents the exact location of\r\na gas/oil contact. The oil-bearing zone extends from 2352 m 2358.5 m. The oil\r\nwater contact at 2358.5 m was picked both from logs and core data. Three cores\r\nwere cut in the Stø formation (2324 m to 2400 m). A total of 9 FMT runs were\r\nperformed; two to obtain pressure points and 7 to obtain segregated samples.\r\nThe first run resulted in 32 pre test pressure points out of 38 attempts, in\r\nthe interval 2323.5 m to 2369.0 m. Eighteen points were taken in the gas zone,\r\n6 in the tight zone, 4 in the oil zone and 4 were in the water zone. The second\r\nrun resulted in 9 pre test pressure points of nine attempts in the interval\r\n2358 m to 2361 m. Seven attempts to obtain segregated samples resulted in 5\r\ngood samples, two at 2355 m, one at 2326 m, and two at 2353.5 m.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 6\r\nJune 1986 as an oil and gas discovery.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eDue to the presence of hydrogen sulphide\r\nin the well, no tests were performed. \u003c/p\u003e\r\n\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"553","properties":{"OBJECTID":553,"wlbNpdidWellbore":910,"wlbName":"6507/6-1","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 6507/6-1 was drilled close to the\r\nhighest point of the main structure in the block. The prospect is defined at\r\nthe Late Kimmerian Unconformity along the crest of the NNE-SSW striking\r\nNordland Ridge. The primary objective of the well was to test the hydrocarbon\r\npotential and reservoir quality in the main structure. In addition the well was\r\nexpected to obtain stratigraphic information of a complete Triassic sequence.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe prognosed depth was 4030 m.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 6507/6-1 was spudded with\r\nWi1h. Wi1helmsen Offshore Services semi-submersible installation Treasure Saga\r\n15 June 1986 and drilled to TD at 4040 m in Early Triassic rocks. The well was\r\ndrilled with spud mud to 584 m, with gel mud from 584 m to 975 m, with\r\nGypsum/Polymer mud from 975 m to 1611 m, with NaCl saturated mud from 1611 m to\r\n3165 m, and with a gel mud again from 3165 m to TD. Drilling proceeded without\r\nsignificant problems.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe larger part of Tertiary, the whole\r\nCretaceous sequence, and most of the Jurassic was missing in the well. Late\r\nPliocene sediments were found to rest directly on Early Jurassic sediments. The\r\ntop of the reservoir (Åre Formation) came in at 1018 m. It contained 7 m of\r\nmethane bearing sandstone. The gas water contact was estimated at 1030 m. The\r\nTriassic grey beds came in at 1376 m. Apart from a weak cut fluorescence at\r\n1032 m on a core from the Åre Formation no show was recorded throughout the\r\nwell. Two cores were cut in the interval 1023 m to 1056 m in the Åre fm. and two\r\ncores were cut further down in the intervals 3041 m to 3045.2 m (Middle to\r\nEarly Triassic) and 3995 m to 4013.2 m (Early Triassic). A FMT segregated\r\nsample was taken at 1028 m. It contained no oil, only gas close to 99% methane\r\nwith traces of other constituent gasses including heavier hydrocarbon gases. A\r\ntotal of 265 sidewall cores were recovered, of which 213 were taken in Triassic\r\nrocks.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was plugged and abando","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"554","properties":{"OBJECTID":554,"wlbNpdidWellbore":911,"wlbName":"6507/2-1","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 6507/2-1 is located on the Dønna\r\nTerrace, offshore Mid Norway. The primary objective of the well was to test the\r\nhydrocarbon potential of Middle and Early Jurassic sandstone sequences. Secondary\r\nobjective was to examine the possibilities of Cretaceous sand in the area. \u003c/p\u003e\r\n\r\n\u003cp\u003eIt was expected that the primary target, the\r\nMiddle Jurassic Tomma sandstone (Fangst Group in today?s nomenclature) would be\r\nencountered at ca 3848 m whilst the Early Jurassic Aldra sandstone (Tilje\r\nFormation) was prognosed at ca 4158 m. Expected total depth for the well was\r\n4823 m +/- 200 m or about 50 m into Triassic aged sediments.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 6507/2-1 was spudded with the\r\nsemi-submersible installation Polar Pioneer on 24 June 1986 and drilled to TD at 4477 m in Late Triassic claystones and siltstones of the Åre Formation. The\r\nwell had 29% down time, due mostly to problems with the seal assemblies and\r\ntechnical sidetracking. The sidetrack was kicked off from 3285 m after the pipe\r\nhad stuck twice, at 3432 m and 3430 m. The well was drilled with seawater and\r\nhigh viscosity pills down to1064 m, with KCl/polymer mud from 1064 m to 3655 m\r\n(including sidetrack), and with gel/lignite/resinex mud from 3655 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well penetrated several sandy intervals\r\nin the Cretaceous, the most important beeing a thin Lysing Formation sand from\r\n2874 to 2879 m, and an Intra-Lange Formation sandy sequence from 3425 m to 3490\r\nm. The Jurassic sandstones of the Fangst Group were encountered at 3858 m. Oil shows;\r\nstaining and fluorescence were observed sporadically throughout the well from\r\n2800 m to 4375 m. The strongest oil shows were observed in the Lysing and Lange\r\nFormation sandstones, and from 3858 m down to 3956 m in the Fangst and Båt\r\nGroups. Well site geochemical analyses indicated two source rock intervals in\r\nthe well. The sequence from 3610 to 3858 m (the Viking Group) was considered to\r\nbe a fair source rock containing mature Type II margina","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"555","properties":{"OBJECTID":555,"wlbNpdidWellbore":912,"wlbName":"6407/6-2 R","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 6407/6-2 R is a re-entry of the\r\n6407/6-2, which was terminated at 524 m due to a blow out from a shallow gas\r\nzone. The purpose of the re-entry was plugging and permanent abandonment.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 6407/6-2 was re-entered with\r\nthe semi-submersible installation Ross Rig on 8 May 1986. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was plugged back to 330 m before\r\nRoss Rig had to terminate operations and leave the locations for drilling well\r\n7121/5-2 in the Barents Sea. The vessel Bucentaur would complete remaining\r\nplugging. The re-entry was suspended on 20 May 1986.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was performed.\u003c/p\u003e\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"556","properties":{"OBJECTID":556,"wlbNpdidWellbore":915,"wlbName":"34/8-2","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 34/8-2 was drilled ca 5 km east of\r\nthe 34/8-1 Visund Discovery well in the northern North Sea. It was drilled on\r\nthe northern compartment of the same structure as the 34/8-1 well, a rotated\r\nfault block flanking the Viking Graben. This northern compartment ("A-North")\r\nmight be separate from the southern by a sealing fault. The main objective of\r\nwell 34/8-2 was to prove hydrocarbons in the Stafjord Formation of the A-North compartment.\r\nThe planned TD was ca 50 m into the Triassic Lunde Formation.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 34/8-2 was spudded with the\r\nsemi-submersible installation Polar Pioneer on 4 October 1986 and drilled to TD\r\nat 3240 m in the Late Triassic Lunde Formation. The rig had to be moved and the\r\nwell was re-spudded twice before the 36" hole could be finished. Otherwise\r\nno significant problems were encountered in the operations. The well was\r\ndrilled with seawater and hi-vis pills down to 1205 m and with KCl/polymer mud\r\nfrom 1205 m to TD. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eA unit assigned to the Late Jurassic\r\nDraupne Formation was penetrated from 2896 to 2912.5 m. Below Draupne a complete\r\nDunlin Group (Drake-Cook-Burton-Amundsen) was penetrated down to 3001 m where\r\nthe Statfjord Formation was encountered. The target Statfjord Formation was\r\nwater bearing, and the only hydrocarbon indications in the well were oil shows\r\non sandstone stringers in the Shetland Formation and weak fluorescence on\r\nDraupne Formation claystone \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eOne core was taken in the well in the\r\nupper part of the Statfjord Formation from 3008 - 3020 m. The recovery was\r\n11.75 meters, 98%. RFT pressure recordings were performed through the Statfjord\r\nFormation and the Lunde Formation. The pressure tests in the Stat","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"557","properties":{"OBJECTID":557,"wlbNpdidWellbore":921,"wlbName":"9/3-1","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 9/3-1 was drilled on a salt induced\r\ndomal trap developed at the edge of the Stavanger Platform. The main objective\r\nof the well was to evaluate the sandstones of the Middle Jurassic Vestland\r\nGroup at a prognosed depth of 1805 m. The well was designed to achieve a valid\r\ntest of the prospect with one well, and to ensure a satisfactory tie of well\r\nresults to existing seismic data. The prognosed TD was 2125 m. The well was\r\nplanned to fully penetrate the reservoir sequence and proceed 50 m deeper than\r\nthe crest, into the underlying rocks of Triassic age.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 9/3-1 was spudded with the\r\nsemi-submersible installation Borgny Dolphin on 29 July 1986 and drilled to TD\r\nat 1972 m in the Triassic Skagerrak Formation. Drilling proceeded without\r\nsignificant problems.\u003c/p\u003e\r\n\r\n\u003cp\u003eTop Sandnes Formation came in at 1788 m,\r\n18 m above prognosed depth. The reservoir was water bearing with no trace of\r\nhydrocarbons. The Vestland Group was found to be 167 m thick with porosities up\r\nto 29.5%. Permeability measurements from the core in the Sandnes Formation gave\r\nan average value of about 1000 mD, but as high as 4700 mD in one instance. No\r\nincrease in background gas and no fluorescence or other hydrocarbon indications\r\nwere observed on cuttings or on any of the 70 sidewall cores recovered. The Tau\r\nFormation shales had excellent source rock properties with TOC in the range 1.5\r\n% to 4.5 % and hydrogen indexes in the range 100 to 500 mg HC/g TOC. Coals of\r\nthe Lower Sandnes Formation and in the Bryne Formation also showed excellent\r\nproperties with hydrogen indexes up to 465 mg HC/g TOC. No migrant hydrocarbons\r\nwere however indicated by the organic geochemical analyses, and all formations\r\npenetrated by the well were immature for generation of petroleum and. One core\r\nwas cut in the interval 1799 -1814 m in the Sandnes Formation. The RFT tool was\r\nrun in the bottom hole section over the reservoir and 8 good pressure points\r\nconfirmed ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"558","properties":{"OBJECTID":558,"wlbNpdidWellbore":922,"wlbName":"6507/7-6","wlbHistory":"\r\n\u003cp\u003eWell 6507/7 6 is an appraisal well on the\r\ncrest of the Heidrun field structure on Haltenbanken off shore Mid Norway. The\r\nstructure is a fault wedge. The main objectives of the well were to establish\r\nthe Ti1je gas/oil contact, to define Tilje and Åre oil properties, and to\r\ninvestigate the Åre oil/water contact. In addition, the well was expected to\r\nprove Fangst erosion and established lateral continuity of Tilje reservoir\r\nproperties.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eAppraisal well 6507/7 6 was spudded with\r\nthe semi-submersible installation Nortrym on 23 July 1986 and drilled to TD at 2525 m in Early Jurassic sediments of the Åre Formation. At 419 m the drill\r\nstring torqued up and spun out five joints below the kelly, dropping the string\r\nto the seabed. The well was re-spudded after being moved approximately 8 m, and\r\nthis time drilling proceeded without significant problems. The well was drilled\r\nwith seawater and pre-hydrated gel sweeps down to 1030 m and with KCl/polymer\r\nmud from 1030 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eOil shows were recorded in 3 m thick\r\nsandstone at 2096 m in the Cretaceous. A marked unconformity separates the\r\nMiddle Jurassic from the overlying Late Cretaceous sequence. The total hiatus\r\nwas from Aalenian-Bajocian to Campanian-Santonian. Top Middle Jurassic Fangst\r\nGroup, Ile Formation was encountered at 2144.5 m and was gas bearing. From good\r\nquality RFT pressure data, cores, and electric logs a gas/oil contact was established\r\nat 2339 m in the Tilje Formation and the oil/water contact at 2440 m in the Åre\r\nFormation. Shows continued down to 2445. Below this depth no shows were\r\nreported.\u003c/p\u003e\r\n\r\n\u003cp\u003eA total of 191 m core was recovered from\r\nthe well. Two cores were cut from the Early Cretaceous through the Fangst Group\r\nand into the top Båt Group (2129 - 2185 m), and eight cores were cut from the\r\ngas zone in the lower part of the Tilje Formation, through the OWC and into the\r\nÅre Formation (2305 - 2462 m). One RFT run was made in the 12 1/4" hole. A\r\nwater sample was at","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"559","properties":{"OBJECTID":559,"wlbNpdidWellbore":925,"wlbName":"6607/12-1","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 6607/12-1 is located in the western\r\npart of the Dønna Terrace in the Norwegian Sea off shore Mid Norway. It was\r\ndesigned to test a structure in the north-western part of the block. The main\r\nstructuration was seen at top Brygge Formation and top Tare Formation. A\r\nsecondary structure was mapped at an intra Cretaceous marker. The top of the Shetland\r\nGroup showed an anomalous graben-like development without structural closure. The\r\nwell was located close to or at the highest structural point of all closed\r\nlevels. The main objectives of the well were to test for hydrocarbons at all\r\nclosed levels of the main structure, to test the contents of the anomalous\r\ngraben feature seen at top Shetland Group level, and to test the upper part of\r\nthe Cretaceous section west of the Nordland Ridge for potential source rocks. The\r\nprognosed depth was 3500 m.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 6607/12-1was spudded with\r\nthe semi-submersible installation Henry Goodrich on 19 July 1986 and drilled to TD at 3521 m in the Late Cretaceous Shetland Group. Down to 1440 m\r\ndrilling proceeded without significant problems. At this depth there was\r\nexperienced a loss of mud to the formation, but the well was stabilised. The\r\nwell was drilled with bentonite mud down to 765 m, with polymer mud from 765 m\r\nto 1526 m, and with Lignosulphonate mud from 1526 m to TD. \u003c/p\u003e\r\n\r\n\u003cp\u003eOnly thin levels of water bearing\r\nsandstones were encountered. The main target (Brygge Formation) came in at 1398\r\nm, 43 meter shallower than prognosis with claystones and a few stringers of\r\nlimestone and sand. The Cretaceous section came in at 1725 m. The main\r\nlithology here was multicoloured claystone with stringers of white, hard limestone.\r\nA fault zone, rich in dolomite and calcite alternating with limestone were\r\npenetrated at 2666 to 2672 m. Total gas of 38% were recorded from this interval,\r\notherwise no other major shows were recorded during drilling or coring. Minor\r\nshows, however, were recorded ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"560","properties":{"OBJECTID":560,"wlbNpdidWellbore":928,"wlbName":"6407/6-2 R2","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 6407/6-2 R2 is the second re-entry\r\nof the 6407/6-2, which was terminated at 524 m due to a blow out from a shallow\r\ngas zone. The purpose of the re-entry was plugging and abandonment.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 6407/6-2 was re-entered with\r\nthe vessel Bucentaur on 13 June 1986. \u003c/p\u003e\r\n\r\n\u003cp\u003eIt was plugged and abandoned as a junked\r\nwell on 24 June 1986.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was performed.\u003c/p\u003e\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"561","properties":{"OBJECTID":561,"wlbNpdidWellbore":933,"wlbName":"6507/8-1","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 6507/8-1 was drilled on the eastern\r\npart of the Heidrun Discovery. The primary objective was to ascertain that the\r\nHeidrun field extension into the 6507/8 block and to verify reserve\r\ncalculations. Secondary objectives were to verify geological model and\r\nstructural interpretation, and define oil water contact in the Tilje Formation.\r\nIt was also intended to provide more information on reservoir characteristics\r\nand hydrocarbon fluids, and maximum input of data for reservoir simulation\r\nstudies. The Fangst Group was expected at 2245 m, and the Tilje Formation at\r\n2340 m. Prognosed TD was 2590 m.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 6507/8-1 was spudded with\r\nthe semi-submersible installation Dyvi Delta on and drilled to TD at 2600 m in\r\nEarly Jurassic sediments of the Åre Formation. Drilling proceeded without\r\nsignificant problems. The well was drilled with seawater and hi-vis pills down\r\nto 1063 m, with KCl/polymer mud from 1063 m to 2235 m, and with\r\ngel/polymer/lingo mud from 2235 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe only oil shows reported above the target\r\nreservoir were on sandstone in a cuttings sample at 2235, and on limestone in a\r\nSWC at 2238 m, both samples from the Melke Formation. The Middle Jurassic\r\nFangst Group was penetrated at 2248 m and the Early Jurassic Tilje Formation at\r\n2386.5 m. These reservoir sandstones were found to be hydrocarbon bearing with\r\na gas/oil contact at 2312 m and an oil/water contact at 2480 m. \u003c/p\u003e\r\n\r\n\u003cp\u003eA total of 9 cores were cut from 2249 m\r\nto 2469 m in the Garn, Not, Ile, Ror, and Tilje Formations. Core no 1 from the\r\nGarn Formation was loose sand and was lost on the drill floor while recovering\r\nfrom core barrel. One relatively good RFT fluid sample was taken at 2317 m. It\r\ncontained oil with a density of 0.88 g/cc (29 deg API).\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 9 December 1986 as a gas and oil appraisal.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eTwo DST tests were performed in the Tilje\r\nFormation.\u003c/p\u003e\r\n\r\n\u003cp\u003eDST","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"562","properties":{"OBJECTID":562,"wlbNpdidWellbore":935,"wlbName":"6407/2-3","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 6407/2-3 was drilled down dip on the\r\nDelta structure on the southern fault compartment of the Midgard Field off\r\nshore mid Norway. The primary objectives were to test for hydrocarbons in the Middle\r\nJurassic Fangst Group, and establish the hydrocarbon contact. Secondary\r\nobjectives were testing the thickness and facies development of reservoir units\r\nin response to growth faulting. Shallow gas was expected at several levels due\r\nto experience from nearby wells. Fangst Group was prognosed to come in at 2417\r\nm, gas/oil contact at 2514 m, and the oil/water contact at 2525 m. TD was\r\nexpected to be 3050 m.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 6407/2-3 was spudded with the\r\nsemi-submersible installation Treasure Saga on 7 November 1986 and drilled to\r\nTD at 3050 m in Early Jurassic sediments of the Åre Formation. Gas peaks above\r\n1% gas value were observed at 532 m, 590 m, 630 m, 755 m, and 802 m, the two\r\nlatter showing the highest values at approximately 1.8%. The whole section was\r\ndrilled using relatively high mud weights around 1.15 g/cm, which makes the\r\nrecorded gas values significant. While tripping out at 2645 m prior to logging,\r\nthe string got stuck. After nine days of fishing it was decided to sidetrack. The\r\n9/58" casing was set at 2371 m and the sidetrack was kicked of at 2387 m. The\r\nwell was drilled with spud mud down to 915 m and with gypsum/polymer mud from\r\n915 m to 2645 m where the pipe stuck. No wire line logs were run in the\r\ninterval 2432 - 2465 in this hole, only MWD. The final 8 1/2" sidetrack\r\nfrom 2371 m to TD was drilled with gel mud.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe Fangst Group came in at 2427 m, ten\r\nmeters below prognosis. It was gas-filled down to a gas/water contact at 2523 m\r\n(2521 m TVD RKB). No oil leg could be seen. No shows were seen in cuttings, but\r\npoor shows with good hydrocarbon odour were described on cores down to 2526 m\r\nin the Ile Formation. Fluorescence was very weak blue white and cut reaction\r\nvery slow. Weak dark yellow","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"563","properties":{"OBJECTID":563,"wlbNpdidWellbore":936,"wlbName":"6608/11-1","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 6608/11-1 was drilled on the\r\nNordland Ridge, west of the Helgeland Basin and east of the Norne Field area.\r\nThe Primary objective was sandstones of Middle to Early Jurassic age. The well\r\nshould drill into Triassic deposits expected at 2010 m and TD was planned at\r\n2095 m.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 6608/11-1 was spudded with\r\nthe semi-submersible installation Dyvi Stena on 19 July 1986. Due to unexpected\r\ngeological development, the well was terminated already at 1620 m in Late\r\nTriassic Grey Beds. Drilling proceeded without significant problems. The well\r\nwas drilled with seawater bentonite spud mud down to 695 m, with KCl/polymer\r\nmud from 695 m to 1619 m, and with bentonite/polymer mud from 1619 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well penetrated Pliocene rocks with\r\ntraces of tuff, which were interpreted as re-worked Paleocene tuffaceous rocks.\r\nDue to erosion these Pliocene rocks were situated on top of the Paleocene\r\ndeposits, implying that most of the Tertiary rocks are missing. The Paleocene sediments\r\nwere resting on Early Jurassic sediments, Åre Formation at 1233 m. Only the\r\nlowermost part of the Åre Formation was present due to erosion, implying that\r\nthe whole of the Cretaceous and most of the Jurassic succession is missing in\r\nthe well. The penetrated Åre Formation consisted of interbedded sandstones and\r\nclaystones with minor coal beds. The electrical logs showed that the formation\r\nwas water filled. No shows were reported from any section in the well neither\r\non-rig, or from post-well geochemical analyses. \u003c/p\u003e\r\n\r\n\u003cp\u003eOne core was cut in the interval 1372 -\r\n1397.7 m in Triassic rocks. No wire line pressure data or fluid samples were\r\ncollected in the well.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 13\r\nAugust 1986 as a dry well\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was performed\u003c/p\u003e\r\n\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"564","properties":{"OBJECTID":564,"wlbNpdidWellbore":937,"wlbName":"30/9-2 R","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThe wildcat 30/9-2\r\nwas planned as the first well on the Gamma structure in block 30/9. Well 30/6-9\r\nhad previously penetrated the structure but this well failed to encounter the\r\noil/water contact. The primary objectives of 30/9-2 were to verify the reserve\r\nestimate for the main part of the gamma structure and penetrate the oil/water\r\ncontact in the lower part of the Brent Group. Additional objectives were to\r\nobtain core material from the oil zone in the Etive Formation and perform a\r\nwater injection test in this, obtain information on the quality of the\r\nreservoir in the water zone and stratigraphical information on the southern\r\npart of the Gamma structure.& The well\r\nwas temporarily abandoned for about one year and then re-entered for an\r\nextended test.\u003c/p\u003e\r\n\r\n\u003cp\u003e \u003c/p\u003e\r\n\r\n\u003cp\u003e \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 30/9-2\r\nwas spudded with the semi-submersible installation \"Nortrym\" on 1\r\nApril 1983 and drilled to a total depth of 2830 m in the Early Jurassic Dunlin\r\nGroup. The well was drilled using water-based mud down to the 12 1/4\" hole\r\nat 1715 m. The 12 1/4\" hole was drilled to TD using oil based mud\r\n(\"ENVIROMUL\" and \"IL 2832 oil\" as oil base). While running\r\nthe 13 3/8\" casing, this got stuck at 1334 m. The casing was worked free\r\nusing diesel in the mud and the casing was set at 1680 m. After drilling the 12\r\n1/4\" hole to 2203 m the drill pipe got stuck with the bit at 2170 m.\r\nSeveral unsuccessful attempts were made to free the pipe. The drill pipe was\r\nthen backed off and the well was cemented back and sidetracked from 1482.5 m. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe Brent Group\r\nsandstones (2578-2767 m) RKB were hydrocarbon bearing down to 2737m where an\r\noil/water contact was encountered within the Etive Formation sandstones\r\n(2698-2767m).& No additional hydrocarbon\r\nbearing reservoirs were encountered by this well. Poor hydrocarbon shows\r\nreported from Upper Cretaceous limestones were considered uninteresting. The\r\nNess Formation (2578-2698 m) consisted of","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"565","properties":{"OBJECTID":565,"wlbNpdidWellbore":940,"wlbName":"34/8-3","wlbHistory":"\r\n\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 34/8-3 was drilled on the\r\nA-structure on the Visund Field. This is a NNE-SSW oriented elongated fault\r\nblock with the Pre-Cretaceous strata dipping towards WNW. The A-Central fault\r\ndivides the A-structure into the A-North and A-South compartments. The primary\r\nobjectives of the well were to test the hydrocarbon potential of the Brent\r\nGroup on the A-North compartment. Planned TD was 50 m into the Statfjord\r\nFormation.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 34/8-3 was spudded with the\r\nsemi-submersible installation Polar Pioneer on 14 July 1988 and drilled to TD\r\nat 3328 m (3320 m TVD) in the Early Jurassic Statfjord Formation. There were no\r\nproblems with shallow gas. 9 5/8" casing was set at 2597 m instead of 2800\r\nm due to higher pressure than prognosed in formation of Cretaceous age. Below\r\n2600 m the well started to build some angle, up to 9.6 deg at the most. This\r\nresulted in 8 meter discrepancy between measured depth and vertical depth\r\ntowards TD. The well was drilled with seawater and hi-vis pills down to 1302 m\r\nand with KCl/polymer mud from 1302 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eOil shows were recorded in thin sandstone\r\nstringers in the Kyrre Formation between 2364 m and 2555 m. The Brent Group was\r\nencountered at 2837 m. It contained a 90 m gas column and a 13 m oil column. The\r\ngas/oil contact was at 2929 m. The oil/water contact could not be established,\r\nbut DST 1 produced clean oil from the interval 2935 to 2947 m. Oil shows were\r\nrecorded on sandstone on cores down to 2951 m.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eSeven cores were cut in the interval\r\n2839.0 to 2957.5 m in the Brent Group. The core depths are 1 m shallow compared\r\nto logger's depth. One RFT wire line fluid sample was taken at 2936 m. The 2\r\n3/4 gallon chamber con","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"566","properties":{"OBJECTID":566,"wlbNpdidWellbore":943,"wlbName":"34/4-7","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 34/4-7 was drilled in the\r\nnorth-eastern margin of the Snorre Field. The Late Triassic - Early Jurassic\r\nreservoirs of the Snorre Field are made up of a complete series of rotated\r\nfault blocks dipping between 5 and 12 degrees towards west and northwest. The\r\nprimary purpose of the well was to assess the upper part of the Lunde\r\nFormation. The well was located to provide data on the reservoir quality of\r\nboth oil and water bearing parts of upper Lunde, and to investigate potential changes\r\nin porosity and permeability across the oil/water contact. Further objectives\r\nwere to verify a revised velocity model for the 34/4 part of the Snorre Field\r\nand reduce structural uncertainty.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 34/4-7 was spudded with the\r\nsemi-submersible installation Treasure Saga on 17 February 1987 and drilled to\r\nTD at 2950 m in the Late Triassic Lunde Formation. Drilling proceeded without\r\nsignificant problems. The 26" section was drilled first as a 17 1/2"\r\npilot hole down to 915 m as a precaution against shallow gas, then opened up to\r\n26" with an underreamer. The well was drilled with seawater and bentonite\r\ndown to 470 m, with gel mud from 470 m to 915 m, with gypsum/polymer mud from\r\n915 m to 2407 m, and with KCl mud from 2407 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eApart from the Pliocene Utsira Formation\r\nat 1062 m and some minor sandy intervals in Middle Oligocene to Late Miocene,\r\nthe upper section down to Triassic consists mainly of claystones. No Jurassic\r\nsediments were encountered in the well. The Triassic Lunde Formation was\r\nencountered at 2502 m, 35 m deeper than expected and is composed of sandstones\r\nwith minor siltstones in the upper part. From 2736 m the Lunde Formation consists\r\nof interbedded sandstone, claystone and limestone","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"567","properties":{"OBJECTID":567,"wlbNpdidWellbore":947,"wlbName":"34/7-10","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 34/7-10 was drilled on the southern\r\nend of the Snorre Field. The primary purpose of well 34/7-10 was to prove\r\nStatfjord Group reserves in the south-east Snorre. Further objectives were to\r\ntest the Statfjord Group thickness and sand distribution, to test the extent\r\nand quality of the middle Statfjord member and to establish a Statfjord Group\r\nOWC and reservoir parameters of the Statfjord Group and underlying upper Lunde Formation.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 34/7-10 was spudded with\r\nthe semi-submersible installation Treasure Saga on 26 August 1986 and drilled\r\nto TD at 3000 m in the Late Triassic Lunde Formation. Drilling proceeded\r\nwithout significant problems. The well was drilled with spud mud down to 430 m,\r\nwith gel mud from 430 m to 918 m, with gypsum/polymer mud from 918 m to 2413 m,\r\nand with KCl mud from 2413 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eApart from the sandy Utsira Formation of\r\nLate Miocene age, a Late Oligocene (1314 - 1324 m) and a Late Eocene (1377 -\r\n1387 m) sandstone unit within the Hordaland Group, the upper section down to\r\nJurassic proved mainly claystones. The Jurassic consists of a silty Dunlin\r\nGroup and a sandy Statfjord Formation. The Triassic consists of claystones with\r\nminor sandstones in the upper part and alternating sandstones/ claystones from\r\n2800 m and down to TD. First traces of shows were seen at 2120 m in silty\r\nlaminas of the Shetland Group. These are described as weak dark yellow\r\nfluorescence with slowly streaming light yellow cut. From 2250 m and down to\r\ntop Statfjord Group oil reservoir at 2531.5 m silt and sandstone show weak to moderate\r\ndull yellow to bright yellow fluorescence and slowly streaming blue white to\r\nmilky white cut. The residue is yellow to light brown in colour. Below the OWC\r\nat 2621 m sh","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"568","properties":{"OBJECTID":568,"wlbNpdidWellbore":949,"wlbName":"6406/3-3","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 6406/3-3 was drilled to appraise the\r\nsouthern part of the Beta structure, named Smørbukk South. This well was the\r\nfourth well on Smørbukk South, and it was a joint well between licenses PL 091\r\nand PL 094. The primary target for the well was sandstones in the Middle-Early\r\nJurassic age Halten Group (present nomenclature: Fangst and Båt Groups). The\r\nwell location was chosen so that the Tomma I Formation (Garn Formation) was\r\nexpected to be hydrocarbon bearing with hydrocarbon/water contacts in the Tomma\r\nIII - Aldra Formations (Ile - Tilje Formations).\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eAppraisal well 6406/3-3 was spudded with\r\nthe semi-submersible installation Dyvi Delta on 4 August 1986 and drilled to TD\r\nat 4416 m in the Early Jurassic Åre Formation. Operations went without\r\nsignificant incidents and were finished twenty days ahead of schedule. Only\r\n5.2% rig time was registered as down time. The well was drilled with\r\nseawater/hi-vis pills/bentonite down to 1070 m, with gypsum/polymer mud from 1070\r\nm to 2320 m, with gypsum/lignosulphonate/lignite mud from 2320 m to 3936 m, and\r\nwith lignosulphonate/lignite/Anco resin mud from 3936 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe top of the reservoir came in at 3933\r\nm, 49 m deeper than prognosed. Cores showed poor - medium visible porosity and\r\ngood to poor oil shows from the top and down to ca 3955 m (ca 3925 m TVD MSL).\r\nThe oil/water contact was thus almost 65 m higher than the other holes in the\r\nBeta structure. RFT-data indicated that the rest of the Fangst and Båt Groups\r\ncontained water. Weak shows were however recorded on sidewall cores in the\r\ninterval 4210 m to 4262 m in the Ti1je Formation, while weak shows were\r\nrecorded on well site cuttings all through Middle - Early Jurassic down to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eA fixed offset VSP with the source 2.6 km\r\nnorth of the location was shot in order to explain the surprising and negative\r\nresults of the well. The VSP sections indicated a probably sealing, east-west\r\nstriking fault at reser","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"569","properties":{"OBJECTID":569,"wlbNpdidWellbore":1001,"wlbName":"25/1-9","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 25/1-9 was drilled nearby and south\r\nof the Frigg structure close to the UK boarder, and was designed to prove\r\npossible hydrocarbon accumulation in the Frigg Formation and "Cod"\r\nsandstone (Intra Balder Formation Sandstone). A main objective was to verify\r\nthe seismo-stratigraphic interpretation in block 25/1. In addition, the well\r\nwas expected to obtain valuable data input to the Frigg Field reservoir\r\nsimulation study. The prognosed depth was 2813 m, 50 m into the Shetland Group.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 25/1-9 was spudded with\r\nWi1h. Wi1helmsen installation Treasure Scout 9 September 1996 and drilled to TD\r\nat 2807 m in the Late Cretaceous Hardråde Formation. Drilling proceeded without\r\nsignificant problems. The well was drilled with seawater and hi-vis pills down to 990 m,\r\n with KCl/polymer mud from 990 m to 1965 m, and  with PAC/polymer/seawater from 1965 m to TD \u003c/p\u003e\r\n\r\n\u003cp\u003eThe Frigg Formation was encountered at\r\n2035 m. It consisted of very fine to fine, hard sandstones with poor reservoir\r\ncharacteristics down to 2051 m. From 2051 m to 2199 m the lithology was\r\npredominantly massive sandstone with excellent reservoir characteristics. Occasional\r\nstringers of claystone and what was interpreted as concretions of\r\ncalcite-cemented sandstone occurred throughout the section. The lower part,\r\nfrom 2196 m to 2237 m was claystone with a3 m conglomerate at the base.\u003c/p\u003e\r\n\r\n\u003cp\u003eHydrocarbons were encountered in the\r\nFrigg Formation with 2.6 m net pay of gas down to 2054 m and 6.9 m net pay oil\r\ndown to a free water level at 2063 m. RFT pressure measurements gave an oil\r\ngradient corresponding to a fluid density of 0.81 g/cm3. Pore pressure\r\nindicated pressure depletion due to production from the Frigg Field. RFT data\r\nindicated that the Frigg Formation contains small reserves and the discovery\r\nwas considered uneconomic.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe gas/oil contact was defined at 2054\r\nm, and the oil/water contact at 2063 m. Only very weak shows we","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"570","properties":{"OBJECTID":570,"wlbNpdidWellbore":1004,"wlbName":"6506/12-1","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003e\u00A0Well 6506/12-1 was drilled on the Alpha\r\nstructure in the northwest part of the block. The main objective was middle\r\nJurassic sandstones in an anti form structure. The secondary and tertiary\r\nobjectives were Early Jurassic and Triassic sandstones on the same structure.\r\nLate and Early Cretaceous were also considered possible zones of hydrocarbon\r\naccumulations. Further objectives, of a more general exploratory nature,\r\nincluded the sampling of potential source rocks. Total depth was to be in rocks\r\nof Triassic age, or 4000 m in order to satisfy the licence commitment.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well is Type Well for the Tofte,\r\nLange, and Lyr Formation. It is Reference Well for the Cromer Knoll Group and\r\nfor the Springar, Nise, and Kvitnos Formations. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 6506/12-1 was spudded with\r\nthe semi-submersible installation Ross Isle on 16 August 1985 and drilled to TD\r\nat 4924 m in the Early Jurassic sediments of the Åre Formation. Drilling down\r\nto, and cementing the 20" casing, went without problems. While testing the\r\ncasing a leak was discovered. No influx or loss of fluid was observed. Setting\r\na cement plug in the interval 540-590 m solved the problem. A leak-off test\r\nequal to 1.34 g/cm3 below the 20" casing shoe was considered to low, and a\r\ncement squeeze was performed, after which a formation integrity test gave 1.64\r\ng/cm3 without leak off. A cement squeeze also had to be performed to obtain a\r\nsatisfactory leak-off test below the 13 3/8" casing shoe. Pore pressures\r\nwere considerably below prognosed down to this depth. While preparing to run\r\nthe 9 5/8" casing a sealing ring was dislodged and had to be milled. Down\r\nto 4317 m maximum deviation was 3.7 ° and difference between measured and true\r\nvertical depth was not more than 1 m. The last part of the well was however\r\nmore problematic in this respect. At 4925 m it was decided to stop the drilling\r\nas the angle had built up too much, and an RFT-tool was stuck i","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"571","properties":{"OBJECTID":571,"wlbNpdidWellbore":1005,"wlbName":"30/6-13 R","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 30/6-13 R is a re-entry of well\r\n30/6-13, which was suspended after having tested oil and gas in the Brent\r\nGroup. The purpose of the re-entry was permanent abandonment\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 30/6-13 was re-entered (30/6-13 R)\r\nwith the semi-submersible installation Treasure Hunter on 8 September 1986. The well was plugged without any problems.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 11 September 1986 as an oil/gas appraisal well.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was performed.\u003c/p\u003e\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"572","properties":{"OBJECTID":572,"wlbNpdidWellbore":1014,"wlbName":"2/12-1","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 2/12-1 is located in the Feda Graben\r\nn the southern North Sea, ca 1.5 m north of the Danish/Norwegian border. The\r\nmain objective of the well was to prove the extension of the Danish\r\n"Gert" discovery into block 2/12. The primary target was Middle\r\nJurassic sandstones, prognosed at 4826 m. Possible secondary targets were Early\r\nJurassic and Triassic sandstones. Structural closure was not defined at Top\r\nShetland or Base Cretaceous levels, but minor stratigraphic trapping was considered\r\npossible in this area. Prognosed TD was 5125 m.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 2/12-1 was spudded with the\r\nsemi-submersible installation Treasure Scout on 14 October 1986 and drilled to\r\nTD at 4795 m in volcanic breccia of the Early Permian Rotliegend Group. Drilling\r\nproceeded without significant problems down to 3970 m where gas problems were\r\nexperienced. The hole was cleaned up, and dual induction/sonic log was run. Due\r\nto increasing gas recordings 9 5/8" casing was set at 3978 m. The\r\nremaining logging program in this section was therefore not run, and sidewall\r\ncores were not taken. At 4705 m a drill- break was experienced. The hole was\r\ncirculated, tested, and drilled to 4714 m. During logging the tool got stuck\r\nand the string was cut. The fish was stuck at 3842 m, and loosening was\r\nunsuccessful. 7" liner was set at 3826 m and cemented. During circulation\r\nhydrocarbons started to flow in between 9 5/8" shoe and 7" liner. The\r\nwell was closed and heavy mud was squeezed into the formation. After 3 weeks\r\nthe fish was pulled out of the hole. The well was drilled with spud mud down to\r\n1015 m, with KCl/polymer mud from 1015 m to 4050 m, and with Lignosulphonate\r\nmud from 4050 m to TD\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 2/12-1 encountered 71 m of o","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"573","properties":{"OBJECTID":573,"wlbNpdidWellbore":1017,"wlbName":"6407/7-2","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell \u003ca name=\"OLE_LINK2\"\u003e\u003c/a\u003e\u003ca\r\nname=\"OLE_LINK1\"\u003e6407/7-2 \u003c/a\u003ewas drilled on the Njord A-structure in the\r\nsouthern part of the Halten Terrace. The Njord structure is located ca 30 km\r\nwest of the Draugen Field. The primary objectives of the well were to test the\r\nreservoir properties of the pre-Tilje sequence and to find the oil-water\r\ncontact in the central part of the A-structure. By this the volumetric\r\npotential of the structure could be established. The well would furthermore\r\nobtain seismic calibration to the base Cretaceous and intra Jurassic and intra\r\nTriassic events. It should penetrate a flat seismic event at approximately 2570\r\nms TWT. A Rogn Formation sand unit was expected at 2598 +/- 65 m.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 6407/7-2 was spudded with the\r\nsemi-submersible installation Polar Pioneer on 20 November 1986. The 36"\r\nhole was drilled to 361 m where the MWD showed an inclination of 7.1 degrees. A\r\nrespud was thus decided. The well was respudded on 20 November and drilled without\r\nsignificant problems to TD at 3320 m in the Triassic Red Beds. It was drilled\r\nwith spud mud down to 780 m and with KCl/polymer mud from 780 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eNo Rogn Formation was encountered. Hydrocarbons\r\nwere encountered in two different pressured reservoir zones in the Middle to\r\nEarly Jurassic. The upper reservoir was a 14 m gas/condensate zone in the Ile\r\nFormation from 2697.5 m to 2711.5 m. A segregated RFT sample from this zone\r\nrecovered gas and condensate. The lower and main reservoir zone was encountered\r\nfrom 2771 to 2877.5 m in the Tilje Formation and contained oil. Two drill stem\r\ntestes were performed in this zone. The Åre Formation was encountered at 2877.5\r\nm and consisted of sandstones with minor claystones and siltstones. The Åre\r\nFormation sandstones were cemented and with low porosity. The logs and cores\r\nproved the Åre Formation to be water bearing, although moderate quality RFT\r\npressure data gave an oil gradient in the inte","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"574","properties":{"OBJECTID":574,"wlbNpdidWellbore":1024,"wlbName":"6407/6-3","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 6407/6-3 was drilled on the eastern\r\nside of the Halten Terrace, roughly mid-way between the Draugen and Midgard\r\nDiscoveries off shore mid-Norway. It was drilled on the same structure as well\r\n6407/6-2, which was junked due to a disastrous shallow gas blow-out. The\r\nprimary objective was to test for hydrocarbon accumulation in sandstones of Middle\r\nJurassic age (Fangst Group). Secondary objectives were possible hydrocarbon\r\naccumulations in Early Jurassic sandstone, and to verify the geophysical and\r\nstructural interpretation and improve the geological, paleontological and\r\ngeochemical understanding of the area. Total depth was to be in rocks of\r\nTriassic age or 4000 m in order to satisfy the licence commitment.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 6407/6-3 was spudded with\r\nthe semi-submersible installation Dyvi Delta on 13 December 1986 and drilled to\r\nTD at 3220 m in Late Triassic sediments of the Åre Formation. No significant\r\ntechnical problems were encountered in the operations, which were completed\r\nwithin planned time and budget. No shallow gas was encountered in the well. At\r\n512 m, the interval thought to correspond with that which caused the\r\nuncontrolled blow out from well 6407/6-2, a small resistivity peak was\r\nrecorded, although the gamma ray reading remained constant. A negative drilling\r\nbreak was recorded at the same depth but here was no increase in gas. The well\r\nwas drilled with spud mud down to 459 m, with gypsum/polymer mud from 459 m to\r\n2470 m, and with gel/lignite/lignosulphonate mud from 2470 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe Middle Jurassic sandstones were\r\npenetrated at 2461 m and were found to be gas/condensate bearing with a thin\r\nlight oil leg. From FMT pressure gradients, logs and shows on cores an OWC can\r\nbe set at 2583 m. There were shows and petroleum odour all through the\r\nreservoir down to 2583 m. Shows description, RFT pressure measurements, \u00A0DST\r\nresults and geochemical analyses indicated a gas/light oil contact at ca 257","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"575","properties":{"OBJECTID":575,"wlbNpdidWellbore":1026,"wlbName":"31/4-9","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 31/4-9 was drilled as an appraisal\r\nwell on the Brage Field on the Bjørgvin Arch in the North Sea. The main\r\nobjective was to establish the OWC and confirm reservoir trends, hydrocarbon\r\ncolumn and reserve potential in the east flank of the structure. TD was\r\nprognosed at 2500 m, 70 m into the Dunlin Group.\u00A0\u00A0\u00A0\u00A0\u00A0\u00A0\u00A0\u00A0\u00A0\u00A0\u00A0\u00A0\u00A0\u00A0\u00A0\u00A0\u00A0\u00A0\u00A0\u00A0\u00A0\u00A0\u00A0\u00A0\u00A0\u00A0\u00A0\u00A0\u00A0 \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 31/4-9 was spudded with\r\nthe semi-submersible installation Polar Pioneer on 23 January 1987 and drilled\r\nto TD at 2480 m in the Early Jurassic Drake Formation. No significant problem\r\nwas encountered in the operations. The well was drilled with spud mud down to\r\n974 m, with KCl/polymer mud from 974 m to 2027 m, and with NaCl/CaCO3/polymer\r\nmud from 2027 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe Fensfjord reservoir came in at 2168.5\r\nm and consisted mainly of fine to medium grained sandstones grading into and\r\ninterbedded with siltstones. The Fensfjord Formation was oil bearing down to\r\nthe oil-water contact at 2172 m. The Brent sandstone was found to be water\r\nbearing. Oil shows were described in the cored sections from 2103.5 m in the Draupne\r\nFormation down to 2222 m in the Fensfjord Formation.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAn attempt to take two cores in the Tertiary\r\nclaystones failed. Eight cores were cut with good recovery in the interval 2103\r\nto 2222 m in the Heather and Fensfjord formations. RFT oil samples were taken\r\nat 2171.5 m topmost in the Fensfjord Formation\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was permanently abandoned on 7\r\nMarch 1987 as an oil appraisal well.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eTesting\u003c/span\u003e\u003c/b\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eTwo drill stem tests were performed ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"576","properties":{"OBJECTID":576,"wlbNpdidWellbore":1027,"wlbName":"30/9-6","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 30/9-6 was drilled on the C-prospect\r\non the southeast flank of the Oseberg Fault block. The structure is a rotated\r\nfault block with overall easterly dips towards the Horda Platform fault. The\r\nprospect is further bounded by faults to the west and to the northwest. The\r\nprimary objective was to prove hydrocarbons in the Brent Group and verify\r\npossible pressure communication between the C-structure and the Oseberg Field\r\nAlpha structure to the North.\u00A0 \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 30/9-6 was spudded with the\r\nsemi-submersible installation Polar Pioneer on 8 March 1987 and drilled to TD\r\nat 3034 m in the Early Jurassic Statfjord Group. Drilling proceeded without\r\nsignificant problems. The well was drilled with spud mud down to 970 m and with\r\nKCl/polymer mud from 970 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe Brent Group was encountered at 2591 m\r\nand had oil in three differently pressured sand bodies, one in the Tarbert\r\nFormation and two in the Ness Formation. The lowest seen oil was at 2645 m in\r\nthe Ness Formation. Four different pressure regimes were found in the Brent\r\ngroup. The Tarbert Formation has 6 m gross with 4.5 m net pay. The average\r\nporosity is 19% and the average water saturation is 44%. The Ness Formation has\r\n49 m gross (hydrocarbon-bearing interval) with 13.3 m net pay (combining the\r\ntwo oil bearing sand bodies). The average porosity is 23% and the average water\r\nsaturation is 39%. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWeak shows were described in limestones\r\nin the interval 2318 m to 2358 m in the top of the Shetland Group. Otherwise,\r\nno oil shows were described outside of the oil-bearing Brent reservoirs. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eFive conventional cores were cut in the\r\nBrent Group from 2593.5 - 2","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"577","properties":{"OBJECTID":577,"wlbNpdidWellbore":1028,"wlbName":"33/9-13 S","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 33/9-13 S was drilled on the\r\nStatfjord Nord Field on the Tampen Spur area in the North Sea. The primary\r\nobjective was to prove oil in the Brent Group to the northeast of the 33/9-8\r\ndiscovery well. Secondary objective was to test the Statfjord Group in a\r\nposition up-dip of the 33/9-8 location.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 33/9-13 S was spudded with the semi-submersible\r\ninstallation Ross Isle on 14 October 1987 and drilled to TD at 3077 m in the\r\nEarly Jurassic Statfjord Group. The well location was moved ca 300 m to the south-southwest\r\nto avoid a potential shallow gas zone at 381 m. The well was deviated back to\r\nthe original target position with maximum deviation 34.3° at 1739 m. Shallow\r\ngas was encountered at 399.5 m, 399.9m, 404.5 m, and 547 m. No significant\r\nproblem was encountered in the operations. The well was drilled with seawater\r\nand hi-vis bentonite down to 398 m, with gypsum/polymer mud from 398 m to 2378\r\nm, and with lignosulphonate/bentonite mud from 2378 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe Brent Group, Rannoch Formation was\r\nencountered at 2726 m and was completely oil filled down-to 2795 m (2720 m TVD)\r\nwith shows on claystones and siltstones down to top Dunlin Group. The Statfjord\r\nGroup was encountered at 3003 m and was water filled. Shows were described only\r\nwithin the Brent Group.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eFour cores were cut in the Brent and\r\nuppermost Dunlin Groups within the interval 2732 - 2828.3 m. No fluid samples\r\nwere taken on wire line.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was permanently abandoned on 24\r\nDecember 1987 as an oil appraisal well.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eTesting\u003c/span\u003e\u003c/b\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"578","properties":{"OBJECTID":578,"wlbNpdidWellbore":1030,"wlbName":"25/1-8 SR","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe Frigg Field was discovered by well\r\n25/1-1 in 1971 and set in production in May 1977. Well 25/1-8 S was drilled in\r\nthe summer of 1985 to monitor changes in gas/fluid contact, uncover\r\npermeability barriers and pressure gradients in the Frigg Formation, refine the\r\ngeological model, and provide ties for seismic interpretations. Before\r\nproduction started the Frigg Field fluid contacts were: OWC = 1955.9 m TVD MSL\r\nand GOC = 1948.2 m TVD MSL. In July 1985 in 25/1-8 S found the oil-leg to be\r\nall swept with the exception of a very thin oil-layer lifted to 1903.5 m TVD\r\nMSL, 2 m below the new gas/liquid contact, which was now a gas/water contact\r\n(GWC) at 1901.3 m TVD MSL. The objective of the re-entry well 25/1-8 SR was to\r\nmonitor further changes in the GWC.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 25/1-8 S was re-entered\r\n(25/1-8 SR) with the semi-submersible installation Nortrym on 14 February 1987.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe GWC was found at 1898.3 m TVD MSL,\r\nonly 3.2 m higher than in July 1985. The slow water rise was attributed to a\r\nthin shale layer that acted as a barrier for effective drainage.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo cores were cut and no wire line fluid\r\nsamples were taken.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was suspended on 18 February\r\n1987 for later re-entry and monitoring of the reservoir parameters. It is\r\nclassified as a gas appraisal well.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eTesting\u003c/span\u003e\u003c/b\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo drill stem test was performed.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"579","properties":{"OBJECTID":579,"wlbNpdidWellbore":1031,"wlbName":"25/1-7 R","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 25/1-7 was drilled on the main Frigg\r\nstructure close to the UK border. The Frigg Field was discovered by well 25/1-1\r\nin 1971. Production from the field started in 1977. A main objective of well\r\n25/1-7 was to establish a reference monitoring station for the production of\r\ngas from the Frigg Field. The objective of the re-entry 25/1-7 R was to record\r\nthe fluid contacts. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eSemi-submersible installation Nortrym\r\narrived the 25/1-7 location on 8 February 1987. When attempting to connect to\r\nthe well head a fishing net was found wrapped around it. This was removed, and\r\nthe well was re-entered (25/1-/ R) on 10 February 1987. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was logged (2135 m - 1900 m) through\r\ncasing with a Thermal Neutron Decay (TDT) log to determine the fluid contacts. The\r\ncontacts found were: base of deepest gas at 1924 m MSL, top of highest oil at\r\n1929.2 m MSL, and top of highest water at 1931.7 m MSL. From this it was\r\nconcluded: 1) The gas oil contact has risen at least by 13 m from initial, and\r\nabout 11 m of this rise occurred since the 19 April 1985; 2) A gas bearing sand\r\nzone located above the shaly barrier at -1939 m MSL between 1939 m MSL and 1929\r\nm MSL has been swept; 3) The oil water contact has risen by 19 m since 19 April\r\n1985.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was suspended on 26 May 1985 as\r\na gas appraisal well. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eTesting\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo drill stem test was performed.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"580","properties":{"OBJECTID":580,"wlbNpdidWellbore":1036,"wlbName":"25/2-11","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 25/2-11 was the\r\nsecond well to be drilled on the East Frigg Gamma structure in the Viking\r\nGraben. Seismic anomalies indicated shallow gas in the area. The well was\r\nprimarily designed to test the reservoir productivity of the Frigg Formation.\r\nSecondly to test for possible gas accumulation in Late Oligocene sands which\r\nmight represent a continuation of the gas-bearing sands encountered in the\r\n25/2-10 well, which due to technical problems had to be abandoned without\r\nlogging and testing. TD was prognosed to be 2075 m, the Frigg Formation at 1930\r\nm and the Oligocene sands at 1005 m.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eAppraisal well 25/2-11\r\nwas spudded 20 February 1987 by Golar-Nor offshore semi-submersible rig\r\nNordtrym and drilled to TD at 2075 m in rocks of Eocene age.\r\nDue to the seismic anomalies that indicated shallow gas, the well was spudded\r\n100 m north of the original location. \u003c/p\u003e\r\n\r\n\u003cp\u003eHard calcite\r\ncemented sands were encountered in Miocene where unconsolidated sands were\r\nprognosed. This caused 17 extra days of drilling, under-reaming and\r\nsidetracking. Top Oligocene was penetrated 20 m below prognosed depth, and top\r\nFrigg formation came 20 m below prognosis. Both targets proved to be\r\nhydrocarbon bearing. The main hydrocarbon-bearing reservoir encountered in\r\nOligocene was a sand-lense at 1105.5 - 1111.5 m (1079.8 - 1085.8 MSL).\r\nPost-well gas chromatographic analyses of core chip extracts from Oligocene\r\n(1051 m and 1107 m) showed extensively biodegraded oil. The Frigg Formation\r\noil/water contact was encountered at 1975 m, and gas/oil contact at 1960 m.\u003c/p\u003e\r\n\r\n\u003cp\u003eCoring commenced\r\nfrom 1950 m to 1986 m with 50% recovery. Three runs to sample the oil from the\r\nOligocene reservoir interval 1105.5 m to 1111.5 m were made by RFT through\r\ncasing. No hydrocarbons were recovered. A RFT sample from 1967 m in the Frigg\r\nFormation recovered mud filtrate with traces of oil.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was plugged\r\nand abandoned on 10 may 1987 as a gas and oil appr","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"581","properties":{"OBJECTID":581,"wlbNpdidWellbore":1037,"wlbName":"30/6-21","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 30/6-21 was drilled on the Alpha North\r\nstructure in the Oseberg fault block. Well 30/6-7 proved oil in the Ness\r\nFormation in 1982. The main purpose of well 30/6-21 was to test the hydrocarbon\r\ncontent in the Oseberg Formations. The well was located in a position where it\r\ncould be utilized as a subsea oil producer/PTS well.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 30/6-21 was spudded with\r\nthe semi-submersible rig Vildkat Explorer on 22 February 1987 and drilled to TD\r\nat 3100 m in Early Jurassic rocks of the Statfjord Group. Drilling proceeded without\r\nsignificant problems except for some tight hole problems in the upper Oseberg\r\nFormation. The well was drilled with sea water and hi-vis pills down to 664 m\r\nand with Enviromul oil based mud from 664 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eTop Brent Group, Ness Formation was\r\npenetrated at 2575 m and proved to be oil filled down to top Dunlin at 2670.5\r\nm. This was a down-to oil contact. The RFT data showed a fluid density of .66\r\ng/cc. The Ness Formation proved not to be a reservoir rock due to lack of sand,\r\nwhile the Oseberg Formation had a net/gross ratio close to 1.0. The Cook- and\r\nStatfjord formations were both water filled. \u00A0\u00A0\u00A0 \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eFour cores were cut from 2563 m at base\r\nShetland to 2669 m at top Dunlin with close to 100% recovery. RFT fluid samples\r\nwere taken at 2590 m, 2619 m, and 2660 m.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was suspended on 9 April 1987 as\r\nan oil appraisal well.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eTesting\u003c/span\u003e\u003c/b\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eOne Drill Stem Test was performed in the\r\ninterval 2645 to 2657 m in the Oseberg Formation. It produced 342 Sm3 oil and\r","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"582","properties":{"OBJECTID":582,"wlbNpdidWellbore":1038,"wlbName":"9/2-1","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 9/2-1 was drilled in a new separate\r\nstructure and designed to test the hydrocarbon potential of the Egersund Basin.\r\nThe main target of the well was to test sandstones of middle Jurassic age.\r\nFurthermore, the well was expected to improve the paleontological, the\r\ngeological and the geochemical understanding of the area.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 9/2-1 was spudded with the\r\nsemi-submersible installation Dyvi Delta on 21 February 1987 and drilled to TD\r\nat 3756 m in the Triassic Skagerrak Formation. The well was drilled with a\r\n36" bit down to 189 m, but the drill bit got stuck due to boulders and the\r\nstring had to be blown off just above the bit. The well was respudded 23\r\nFebruary 1987 and this time a 17 1/2" pilot hole was drilled before\r\nopening to 36". It was drilled to 587 m without a riser. NPD gave\r\nsuspension from conventional logging through this sequence because the MWD log\r\nwas of good quality, with continuity and correlatable to other wells in the\r\narea. Further drilling proceeded without significant problems. The well was\r\ndrilled with spud mud down to 788 m and with gypsum/polymer mud from 788 m to\r\nTD.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe top of the Jurassic sand (Sandnes\r\nFormation) was reached at 3174 m, 178 m deeper than prognosed. The oil water contact\r\nwas difficult to determine exactly from logs, but was believed to be somewhere\r\nin the transition zone between 3230 and 3239 m. There were good shows down to\r\n3240 m. Core and log analysis indicated a fairly low porosity sandstone with\r\nsmall amounts of silt, shale and limestone. Compaction, quartz cementation,\r\ncalcite cement, and clay minerals occurring as fine-grained pore filling\r\naggregates, are the main porosity-reducing factor in the reservoir. The core\r\nand log analysis indicate a general trend of decreasing reservoir quality with\r\nincreasing depth. The Bryne Formation at 3309 m to 3601 m was water wet.\r\nOrganic geochemical analyses show many intervals with good to excel","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"583","properties":{"OBJECTID":583,"wlbNpdidWellbore":1044,"wlbName":"6508/5-1","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 6508/5-1 was drilled on a structure\r\nlocated in the western part of the Helgeland Basin off shore Mid Norway. The\r\nprimary target was sandstone of the Early/Middle Jurassic Ile Formation. The\r\nTi1je Formation was a secondary target in the case of a shaled out Early/Middle\r\nJurassic sequence acting as a seal.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 6508/5-1 was spudded with\r\nthe semi-submersible installation West Vanguard on 22 April 1987 and drilled to\r\nTD at 2589 m in the Triassic Red Beds. The hole was drilled without significant\r\nproblems and without any signs of shallow gas. It was drilled with seawater and\r\ngel down to 961 m, and with KCl/polymer mud from 961 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe top prospect was encountered at 1778\r\nm and cored. The cored section exhibited excellent porosities with an average\r\nof 32% and permeabilities of generally several hundreds of mD to tens of\r\nDarcies. From petrophysical log evaluation the whole of Ile Formation had a net\r\nto gross of 64% and the same porosity average as in the cored section using a\r\n15% porosity cut off. The Tilje Formation also possessed excellent reservoir\r\ncharacteristics. Reservoir characteristics remained good in the Åre Formation\r\nand Red Beds with an average of 25% porosity at around 2500 m. Unfortunately\r\nthere were no signs of hydrocarbons on the logs and no shows were recorded in\r\nany part of the well, except for cut fluorescence in sidewall cores in\r\nclaystones from the Spekk and upper Melke Formations. The RFT tool was run from\r\n1786 m in the Ile Formation to 2542m in the Red Beds with 13 pressure points\r\nacquired. A clear water gradient of 1.013 g/cm3 was established. Post-well\r\norganic geochemical analyses included in the well completion reports only\r\npartly considered migrated hydrocarbons/shows, but from rock-eval PI data the\r\nlack of shows were confirmed. These analyses also proved excellent source rock\r\npotential in the Spekk Formation, although more gas-prone than further to the\r\nwest an","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"584","properties":{"OBJECTID":584,"wlbNpdidWellbore":1046,"wlbName":"26/4-1","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 26/4-1 was the\r\nfirst well drilled in the Stord Basin. The well was designed to test a\r\nPaleocene mound, and sandstones of Jurassic age within a footwall closure. The\r\nPaleocene sandstone was prognosed to come in at 2268 m. Another primary\r\nobjective was to gain information on reservoir quality and hydrocarbon source.\r\nA secondary target was the Sleipner Formation prognosed at 2783 m. Prognosed TD\r\nwas 3500 m MSL.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 26/4-1\r\nwas spudded with Wi1h. Wilhelmsen semi-submersible installation Treasure Scout\r\non 8 may 1987 and completed 17 July 1987 at a depth of 3690 m in Triassic Hegre\r\nGroup. Drilling proceeded without significant problems, except for several\r\noccurrences of lost circulation due to increasing formation pressure in\r\nTertiary rocks. The well was drilled with seawater and bentonite down to 236 m,\r\nwith seawater / bentonite /PAC from 236 m to 723 m, with KCl / Polymer mud from\r\n723 m to 2680 m, and with seawater / polymer from 2680 to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe Paleocene Mound\r\n(Ty Formation sand) came in at 2246 m. Pressure measurements taken 7 m into the\r\nmounds displayed normal pressure conditions, and the sandstone proved to be\r\nwater bearing. The Jurassic Draupne Formation came in at 2637 m with a total\r\nthickness of 88 m. An extremely radioactive layer was found between 2688 and\r\n2693 m. The Sleipner Formation sandstone came in at 2820 m. Top Statfjord\r\nFormation came in at 3308 m. Sands in Jurassic (Hugin and Statfjord Formations)\r\ndisplayed a very slow white cut fluorescence and traces of oil on cores, but\r\nwere otherwise found dry. Post well geochemical analyses revealed very good\r\nsource rock intervals in the Draupne Formation (oil prone) and the Statfjord\r\nFormation (oil and gas prone). Draupne shale and Sleipner coal are immature\r\nwith Vitrinite reflectance around 0.5 %Ro, while the Statfjord coals may be\r\nmarginally mature with Vitrinite reflectance around 0.6 %Ro and Tmax\r\napproaching 450 °C.\u003c/p\u003e\r\n\r\n\u003cp\u003eFour","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"585","properties":{"OBJECTID":585,"wlbNpdidWellbore":1051,"wlbName":"34/10-32","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 34/10-32 was the fifth well on the\r\nGullfaks South structure. The main objective was to confirm hydrocarbons in the\r\nsouthern part of the structure, and to get data for update of the structural\r\nand geological model of the area. The main target was the Statfjord Formation,\r\nwhere the oil-water contact was expected at 3360 m. Secondary targets were\r\nBrent Group sandstones and the Lunde Formation.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 34/10-32 was spudded 9\r\nApril 1987 by Smedvig semi-submersible installation West Vision and drilled to\r\nTD at 3753 m in the Triassic Lunde Formation. Shallow gas was found in the\r\nneighbouring hole, and it was decided to set the 20" casing early. There\r\nwas one meter of shallow gas in this hole as well, but no problems occurred due\r\nto this. At setting depth of 13 3/8" casing at 1982 m in the Lista\r\nFormation the casing stuck at approximately 1000 m. After several days of\r\nfishing 700 m casing was retrieved, while 300 m dropped to the bottom of the\r\nhole. The well was sidetracked with kick-off point at 1323 m and further\r\ndrilling proceeded without significant problems. The well was drilled with spud\r\nmud down to 350 m, with gypsum/polymer mud from 350 m to 2940 m, and with\r\nlignosulphonate/lignite mud from 2940 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe stratigraphy came in different from\r\nprognosis due to faulting. An 8 m thick Brent Group sequence (Ness Formation) came\r\nin at 3170 m, which was 180 m deeper than prognosed. The section consisted of sandstone/siltstone\r\nand was gas-bearing. The Cook Formation sandstones came in at 3236 m, 207 m\r\ndeeper than prognosed, and were water-bearing. The well penetrated a large\r\nfault at 3316 m within the Amundsen Formation so that a large part of the\r\nAmundsen Formation was missing. Because","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"586","properties":{"OBJECTID":586,"wlbNpdidWellbore":1054,"wlbName":"6407/10-1","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eBlock 6407/10 is an oil prone part of the\r\nHalten Terrace. Well 6407/10-1 is located immediately to the south of the Njord\r\nField in block 6407/7, on compartment B1 of the B-structure. The B-structure is\r\ndown faulted relative to the Frøya High in south-southeast and to the\r\nA-structure in block 6407/7 to the west. The structure is dipping into a small,\r\ndeep basin to the north. The main objectives of the well were to test\r\nhydrocarbon potential of the Garn, Ile and Ti1je Formations in the B-structure.\r\nFurther objectives were to test the geological model and to calibrate the\r\nseismic interpretation and horizon identification. The well location was chosen\r\nto penetrate the target reservoir with an up-dip of less than 15-30x10 6 sm3\r\noil in place, and to penetrate the Tilje Formation within the expected depth\r\nrange of the oil-water contact in the Ti1je Formations in the A-structure.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 6407/10-1 was spudded 7 may\r\n1987 by Polar Frontier Drilling semi-submersible rig Polar Pioneer and drilled\r\nto TD at 3347 m in the Triassic Grey Beds. Due to a shallow gas risk, the well\r\nwas drilled without riser and logged with MWD down to 1100 m. The prognosed\r\nshallow gas levels were drilled without problems and only small peaks on the\r\nlog indicated sand with a certain gas saturation. The 20" casing was\r\nskipped and 13 3/8" casing was set directly. The well was drilled with\r\nseawater and hi-vis pills down to 1117 m and with KCl mud from 1117 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was water bearing with a\r\npossible small amount of gas in the upper part of Ti1je Fm. Some shows were\r\nrecorded in the Ile Formation. The Formation pressures encountered showed that\r\nthe A and B compartments of the Njord Field are not in communication. Five\r\ncores were cut in the intervals 2582 - 2610 m (Rogn Formation), 2748 - 2776 m\r\n(Not Formation), 2817 - 2845 m (Ile Formation), 2845.5 - 2873.5 m (Ile / Ror\r\nFormation), and 2983 - 3011 m (Tilje Formation).\u003c","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"587","properties":{"OBJECTID":587,"wlbNpdidWellbore":1055,"wlbName":"6507/11-4","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 6507/11-4 is located ca 3.5 km north-north\r\nwest of the Midgard Field on the Halten Terrace. The objective was to test the\r\nhydrocarbon potential in Jurassic sandstones in a rotated north-south trending\r\nfault block. Shallow gas was warned at the following levels: 470-532/539- 601-\r\nand 671 m. TD was planned at 2950 m.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 6507/11-4 was spudded by the\r\nsemi-submersible installation Treasure Saga on 16 May 1987, and drilled to TD\r\nat 3045 m in the Early Jurassic Aldra Formation (Tilje Formation). Due to\r\nexcessive deviation during the first 13 m, the TGB was pulled and moved 10 m\r\ntowards east where the well was re-spudded on May 17. Otherwise, drilling\r\nproceeded without significant problems. No shallow gas was encountered at the warned\r\nlevels. The well was drilled with seawater and hi-vis mud down to 817 m, with\r\ngypsum / polymer mud from 817 m to 2655 m, and the remaining 8 1/2"\r\nsection from 2655 m to TD with gel / polymer mud.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe argillaceous Grip Group (Viking\r\nGroup) was encountered at 2530 m, and the sandy Tomma Formation (Fangst Group)\r\nat 2676.5 m RKB. The latter consisted of two sandstone units (Garn and Ile\r\nFormations) separated by a more argillaceous unit (Not Formation). The gross\r\nsand thickness in the two units was 174 m and the porosity was good. The\r\ncalculated average values of log porosity and the net to gross ratio for the Garn\r\nFormation was 24.6% and 0.96 respectively. The corresponding figures for the Ile\r\nFormation were 22.1% and 0.74. The Leka Formation (Ror Formation) consisted mainly\r\nof claystone, while claystone and sandstone were alternating in the Aldra\r\nFormation (Tilje Formation). Sporadic oil fluorescence were observed in\r\nlamellas of silty sandstones in the Late Cretaceous at 2220 m, 2265 m, and 2315\r\nm. No shows were observed in the Jurassic sandstone units. Post-well organic\r\ngeochemical analysis did not confirm the shows in Late Cretaceous, but revealed\r\na possible ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"588","properties":{"OBJECTID":588,"wlbNpdidWellbore":1056,"wlbName":"6507/7-7","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 6507/7-7 was drilled on the southern\r\nflank of the Heidrun Field on the Halten Terrace. The primary objective was to\r\nappraise reserves in this part of the field. Further objectives were to obtain\r\ncores from the Tomma Formation (Fangst Group), to evaluate vertical\r\ncommunication between sandstone units in this section, and to obtain a water\r\nsample from the Aldra (Tilje) Formation.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eAppraisal well 6507/7-7 was spudded with\r\nthe semi-submersible installation Treasure Hunter on 11 May 1987. At 455 m the\r\ndrill string backed off during a connection. Fishing was unsuccessful and an\r\neighty-meter long fish was left in the hole. The rig was moved ca 20 m\r\neastwards and re-spudded on 13 May. The well was drilled to 1035 m in Pliocene\r\nsediments (Naust Formation) where the 20" casing was run and cemented.\r\nWhile pulling out of the hole with the running string, the cement stinger\r\nunscrewed and fell into the casing. Fishing was again unsuccessful and the\r\ndecision was made to plug and abandon. The well was drilled with seawater and\r\ngel all through.\u003c/p\u003e\r\n\r\n\u003cp\u003eOnly MWD logs are available from the\r\nwell. No cores were cut and no wire line fluid samples taken.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 7\r\nJune 1987 as a junk well. Replacement well 6507/7-8 was spudded two days later.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was performed\u003c/p\u003e\r\n\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"589","properties":{"OBJECTID":589,"wlbNpdidWellbore":1057,"wlbName":"6407/9-7","wlbHistory":"\r\n\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 6407/9-7 was located on the crest of\r\nthe \"Husky\" structure approximately 11 km NNE of Draugen well 6407/9-2.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe main objectives of the well were: to\r\nevaluate the hydrocarbon potential of the Middle Jurassic sandstones of the\r\n\"Husky\" prospect; to evaluate the Early Jurassic sands; to fulfil the work\r\nobligation of the licence by drilling a second exploration well into the\r\nTriassic.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 6407/9-7 was spudded with\r\nWilh. Wilhelmsen semi-submersible installation Treasure Scout on 26 April 1988\r\nand drilled to TD at 2561 m in the Triassic Red Beds. The well was drilled with\r\nSeawater and hi-vis pills down to 810 m and with KCl/Polymer mud from 810 m to\r\nTD. The drilling proceeded without problems. No shallow gas was encountered.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe target Middle and Early Jurassic\r\nreservoir sands were well developed, particularly in the Garn Formation. There\r\nwere no signs of hydrocarbons, either within the Jurassic sequence or in the\r\noverlying section. The well was considered a conclusive dry test of the Husky\r\nstructure.\u003c/p\u003e\r\n\r\n\u003cp\u003eNo cores were cut and no fluid samples\r\nwere taken. The well was permanently abandoned on 25 May 1988 as a dry well.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was performed\u003c/p\u003e\r\n\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"590","properties":{"OBJECTID":590,"wlbNpdidWellbore":1062,"wlbName":"2/7-20","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 2/7-20 was drilled on the "South\r\nEldfisk structure", later called Embla. The 2/7-9 well, drilled in 1973,\r\ntested oil at uneconomic rates from a thick pre-Late ?Jurassic sand sequence on\r\nthis structure. Well 2/7-9 established a 111 m pay section with average\r\nporosity of 13% and 55% oil saturation. A clear OWC was found at 4387 m MSL. Following\r\na 1986 re-evaluation of the test it was concluded that the poor test results\r\nmight have been due to mechanical problems. Subsequently the 2/7-20 well was\r\nspudded to test the previously encountered sandstones. The objectives of the\r\nwell were to test "economic" flow rates from sands on the South\r\nEldfisk structure below the Late Jurassic shales of the Mandal Formation. At\r\nthe time of drilling the cost of a subsea completion had been estimated to be US$\r\n12 million which meant that flow rates in excess of 286 m3 oil/day were\r\nconsidered economic. Well 2/7-20 was placed on a separate and higher fault\r\nblock in the structure than the one drilled by 2/7-9.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 2/7-20 was spudded with the\r\nsemi-submersible installation Dyvi Stena on 15 October 1987. The well was re-spudded\r\nthree times because of collapsed hole problems. After drilling riserless to 608\r\nm the lower part of the hole collapsed after encountering a gas sand that\r\nresulted in the loss of drill pipe. The well was sidetracked at 234 m, and 13\r\n3/8" casing was set above the Eocene at 2439 m. A drilling break was\r\nencountered at 4084 m. After drilling a further 2 m, 100% sands with good shows\r\nwere circulated up. High pressures together with the long section of open hole\r\nnecessitated plugging back and sidetracking immediately below the 13 3/8"\r\ncasing shoe. No logs were run at TD in this hole before plugging back. Drilling\r\nthe sid","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"591","properties":{"OBJECTID":591,"wlbNpdidWellbore":1064,"wlbName":"6607/5-1","wlbHistory":"\u003cb\u003e\r\nGeneral\r\n\u003c/b\u003e\r\n\u003cp\u003e\r\nWell 6607/5-1 was designed to test the reservoir potential in the Amundsen prospect on a tilted fault block at the crest of the Bodø High. Middle to Lower shallow marine sandstones of the Båt and Fangst Groups were the primary objectives.\r\nThe main source rock interval was expected to be the Spekk Formation \"hot shale\". In addition the Åre Formation was expected to have source rock potential.\r\n\u003cbr\u003e\r\nCretaceous and Tertiary claystones/shales were prognosed to provide the main top seal on the underlying sandstones. Possible absence of the Middle-Lower Jurassic reservoir was considered the major risk for the Amundsen prospect. Adequacy of source was considered a second major risk. TD was prognosed to 3800 m.\r\n\u003c/p\u003e\r\n\u003cb\u003e\r\nOperations and results\r\n\u003c/b\u003e\r\n\u003cp\u003e \r\nWildcat well 6607/5-1 was spudded by SDS Drilling semi-submersible installation \"Vinni\" 9 June 1987, and completed 11 September 1987 at a depth of 3817 in the Late Cretaceous Lange Formation. Drilling proceeded without significant problems. The well was drilled with bentonite mud to 915 m and with water based KCl mud from 915 m to TD.\r\n\u003cbr\u003e\r\n\u003cbr\u003e\r\nThe primary objects were not penetrated, as the reflectors interpreted as Jurassic, turned out to be of Cretaceous age. Shallow gas was encountered within Pleistocene sediments over the interval 966 m - 1040 m, which correlates well with a strong seismic anomaly which was picked predrill at 977 m. Late Cretaceous rocks were encountered at 2512 m, underlying 2117 meters of Cenozoic clay stones and siltstones. The Late Cretaceous (Basal Maastrichtian-Late Cenomanian) sediments (1305 m) consist predominantly of very fine clastics (clays, claystones, shales and siltstones). Minor fluorescence and cut were observed in intervals below 3385 m in silty, sandy claystones of  Late Cenomanian-Turonian to Turonian-Santonian age. No significant reservoir intervals were penetrated. A few meters of net sand were seen in thin sand beds of Campanian-Santonian age. In addition, weak hydrocarbon shows were encounter","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"592","properties":{"OBJECTID":592,"wlbNpdidWellbore":1066,"wlbName":"7124/3-1","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 7124/3-1 is located east of the Hammerfest Basin on the Nyslepp Fault Complex. Two levels were identified where tests for\r\nhydrocarbons should be performed. The primary target was reservoir rocks of\r\nMiddle Jurassic age, and a secondary target was Late Carboniferous rocks. In\r\naddition the source rock potential of the Triassic rocks should be\r\ninvestigated, as well as the whole stratigraphy from seabed to the prognosed TD\r\nat 4500 M.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well Type Well for the Ørret\r\nFormation and Reference Well for the Bjarmeland Group.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 7124/3-1 was spudded with\r\nthe semi-submersible installation Ross Rig on 29 may 1987 and drilled to TD at\r\n4730 m in rocks of Carboniferous age. Below 633 m the gas values increased\r\nrapidly with average values of 0.5 to 5-6% with a maximum of .10.93%. Due to\r\nthe weak formation at the 30" casing shoe it was not possible to raise the\r\nmud weight above 1.03 g/cc. It was decided to stop drilling at 765 m and set\r\nthe 20" casing because of this. The high gas values were not due to\r\nincreased gas content of the formation, but rather a function of the low mud\r\nweight. Otherwise drilling proceeded without significant problems. The well was\r\ndrilled with spud mud down to 361 m, with gel mud from 361 m to 765 m, with\r\ngypsum / polymer mud from 765 m to 3256 m, and with gel mud from 3256 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well penetrated the Early Jurassic\r\nTubåen Formation at 1284.5 m. The interval 1284.5 m to 1297.5 m contained gas,\r\nwith a one-metre thick oil leg below. The fluid contacts are based on RFT\r\npressure measurements. The average log porosity of the gas zone is 22.8%, and\r\nthe water saturation is 9 %. In the oil leg the average porosity is 26.2%, and\r\nthe average water saturation is 53%. The N/G ratio is 1.0 in both zones. Oil\r\nshows in sandstones were recorded on cores from the oil leg down to1304 m.\r\nBelow this depth several gas charged sandstone horizons yielded notable gas\r\npeaks: ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"593","properties":{"OBJECTID":593,"wlbNpdidWellbore":1068,"wlbName":"6506/12-8","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 6506/12-8 is located in the\r\nHaltenbanken area off shore Mid Norway. It was designed to appraise the\r\nSmørbukk South discovery in the southern part of the block. The main objective\r\nwas to establish productivity in the Garn Formation down flank of well\r\n6506/12-3, the fluid properties, and to provide better understanding of\r\ndiagenesis effects. In the Ile Formation the gas/water contact should be\r\nestablished, and in the Tilje Formation the oil/water and gas/oil contacts\r\nshould be established or confirmed.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eAppraisal well 6506/12-8 was spudded with\r\nthe semi-submersible installation West Delta on 4 June 1988 and drilled to TD\r\nat 4334 m in the Early Jurassic Tilje Formation. The well was drilled without\r\nsignificant problems or incidents. It was drilled with spud mud down to 558 m,\r\nwith gypsum polymer mud from 558 m to 3877 m, and with\r\ngel/lignosulphonate/lignite from 3877 m to TD. Gas bearing shallow sands were\r\npenetrated at 571 to 573 m and at 881 to 885 m.\u003c/p\u003e\r\n\r\n\u003cp\u003eWeak shows were recorded in sands in the\r\nLysing Formation at 3158 - 3185 m. Top of the target reservoir (top Garn\r\nFormation) was encountered at 3875 m, the Ile Formation was encountered at\r\n3992.5 m, and the Tilje Formation was encountered at 4186 m. The logs showed\r\ngood reservoir properties, especially in the Garn Formation. The Garn and the\r\nTilje Formations were tested and found hydrocarbon bearing. The Garn Formation\r\nwas hydrocarbon bearing all through down to the tight sandstones/siltstones of\r\nthe Not Formation. Weak shows were recorded also in the Ile Formation\r\nsandstone, and the logs indicated hydrocarbons down to top Ror Formation at\r\n4065 m. However, no test was conducted in the Ile Formation. In the Tilje\r\nFormation geochemical analyses of the cores showed that the hydrocarbons were\r\ndistributed in distinct zones within the reservoir. The most likely OWC was\r\nestimated at ca 4269 m, but no clear contact was found. \u003c/p\u003e\r\n\r\n\u003cp\u003eEight cores were cut ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"594","properties":{"OBJECTID":594,"wlbNpdidWellbore":1069,"wlbName":"33/9-12","wlbHistory":"\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 33/9-12 was drilled on the Statfjord\r\nØst Discovery on Tampen Spur in the North Sea. The field was discovered in late\r\n1976 by well 33/9-7, which proved oil in the upper portion of the Brent Group.\r\nThe well 34/7-5, which was drilled on the northerly segment of the structure,\r\npenetrated an oil-bearing Brent section down to the same structural level as\r\nseen in well 33/9-7, suggesting communication between the wells. However,\r\nneither well was drilled in a location that could demonstrate oil in the major\r\nLower Brent reservoir or allowed a clear definition of the oil water contact.\u00A0\r\nThe objective of well 33/9-12 was to test the Lower Brent Group and to\r\nestablish the oil-water contact.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 33/9-12 was spudded with\r\nthe semi-submersible installation Ross Isle on 19 June 1987 and drilled to TD\r\nat 2959 m in the Triassic Hegre Group. The well was drilled with spud mud down\r\nto 360 m, with gypsum/polymer mud from 360 m to 2120 m, and with\r\ngel/lignosulphonate mud from 2120 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWeak shows in traces of sand was\r\ndescribed from 2220 m and down in the Shetland Group. Top Brent Group, Tarbert\r\nFormation was penetrated at 2461 m. The Brent Group had a total oil leg of\r\n52.25 metres above the oil-water contact in the Etive formation at 2513.75 m\r\n(2491. 75 m TVD MSL). Oil shows continued down to 2530 m; below this depth\r\nshows became weak and patchy. The Statoil Group was encountered at 2814 m. It\r\nwas water wet and pressure measurements showed that the Statfjord formation is\r\nnot in pressure communication with the Brent group. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThree cores were cut in the interval 2467\r\nm to 2566 m in the Brent Group and into the Uppermost Dunlin Group with 95 to\r\n99.7% recovery.\u00A0 ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"595","properties":{"OBJECTID":595,"wlbNpdidWellbore":1070,"wlbName":"7321/8-1","wlbHistory":"\r\n\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 7321/8-1 is located in the Fingerdjupet  Sub-basin in the Bjørnøya East area. The main target of the well was to test\r\nthe reservoir properties and hydrocarbon potential of Middle to Early Jurassic\r\nsandstones. It was drilled in a position that would leave the minimum of\r\nreserves untested up-dip. Secondary targets were seen in Late Triassic\r\nsandstones and in the Permian sequence. The wildcat well should further\r\nestablish good seismic tie and gather maximum amount of geological information\r\non source, seal and reservoir intervals.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 7321/8-1 was spudded with\r\nthe semi-submersible installation Polar Pioneer 23 June 1987 and drilled to TD\r\nat 3482 m in Late Permian silicified shale of the Røye Formation. Drilling\r\noperations went without significant problems. The well was drilled with\r\nseawater and hi-vis pills down to 818 m, with KCl / polymer mud from 818 m to\r\n2584 m, and with polymer mud from 2584 m to TD. The hole was drilled to 818 m\r\nwithout riser. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe primary target reservoir interval\r\n(expected Stø-Tubåen Formations) was penetrated at 1437 m, 201 m higher than\r\nexpected. The best interval here was from 1437 m to 1567 m, which consisted of\r\na fine-medium grained sandstone with interbedded shales. The sequence had 92 m\r\nnet sand with 17.8 % average porosity. The interval was found water bearing\r\nwith residual hydrocarbon saturation. The Base Late Triassic sandstone interval\r\nwas found water bearing. The prognosed Permian reservoir sequences were found\r\nat 3398 m, 875 m higher than expected. It was poorly developed and merely\r\nconsisted of silicified and pyritised shales and claystones with some minor\r\nweakly calcite cemented, low porosity sandstones. No hydrocarbon indications\r\nwere seen in this section. Shows were recorded on cuttings and cores in several\r\nsequences between 890 m and 1557 m. Shows were also recorded on cuttings from\r\n2618 m to 2628 m. Seven cores were cut in this well. Four of th","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"596","properties":{"OBJECTID":596,"wlbNpdidWellbore":1071,"wlbName":"6507/7-8","wlbHistory":"\r\n                    \u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n                    \r\n                    \u003cp\u003eWell 6507/7-8 is a replacement well for well 6507/7-7 and\r\n                    was drilled on the southern flank of the Heidrun Field on the Halten Terrace.\r\n                    The primary objective was to appraise reserves in this part of the field.\r\n                    Further objectives were to obtain a water sample from the Aldra (Tilje) Formation,\r\n                    evaluate vertical communication between sandstone units in the Tomma Formation\r\n                    (Fangst Group), and to obtain oriented cores from this section for fracture\r\n                    orientation studies.\u003c/p\u003e\r\n                    \r\n                    \u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n                    \r\n                    \u003cp\u003eAppraisal well 6507/7-8 was spudded with\r\n                    the semi-submersible installation Treasure Hunter on 9 June 1987 and drilled to\r\n                    TD at 2855 m in Early Jurassic sediments of the Åre Formation. Some problems\r\n                    with low penetration rate and bit balling occurred in the 17 1/2" section\r\n                    in swelling clay, sometimes interbedded with pebbles. The well was drilled with\r\n                    seawater and gel sweeps down to 1035 m and with KCl/polymer mud from 1035 m to\r\n                    TD.\u003c/p\u003e\r\n                    \r\n                    \u003cp\u003eThe top of the Tertiary was encountered\r\n                    at 604 m. No indications of overpressured shallow gas were seen. The top of the\r\n                    Tomma Formation (Fangst Group) was penetrated at 2436.2 m and consisted of two hydrocarbon\r\n                    bearing sandstone units separated by a ca 2 m thick shaley interval at 2468 m.\r\n                    For the two units as a whole the logs gave an average SW of 19.4% over the 60.6\r\n                    m reservoir and a net/gross ratio of 0.921. RFT pressure data indicated a\r\n                    common pressure regime across the shale band at","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"597","properties":{"OBJECTID":597,"wlbNpdidWellbore":1076,"wlbName":"6507/8-2","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 6507/8-2 was the second well to be\r\ndrilled in the block and is located in the Grinda Graben East of the Heidrun\r\nField. The well was designed to drill and test the hydrocarbon potential of a\r\nclearly defined structure called the Theta structure. Secondary objectives were\r\nto verify the geological model and structural interpretation of the area, and\r\nto improve the paleontological, geological and geochemical understanding of the\r\narea. TD was planned 50 m into Triassic rocks.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 6507/8-2 was spudded with\r\nDyvi offshore semi-submersible rig Dyvi Delta on 15 August 1987 and drilled to\r\nTD at 2690 m in Late Triassic rocks of the ÅÅre Formation. The well was drilled\r\nwith seawater and viscous pills down to 521 m, with KCl/Polymer mud from 521 m\r\nto TD. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe whole of Cretaceous as well as the\r\nLate and Middle Jurassic were missing in the well. Early Jurassic\r\nshale/siltstone (Ror Formation) was encountered at 1890 m and the Early\r\nJurassic Tilje Formation sandstones was encountered at 1945 m. Three cores were\r\ncut. The first was cut in the interval 1894 m to 1915 m in the Ror Formation\r\nwhile the next two recovered 9.5 m from the Tilje Formation. From cores,\r\ncuttings and logs the well was found to be dry all through. The well was\r\nplugged and abandoned on 9 September 1987 as a dry well.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was performed\u003c/p\u003e\r\n\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"598","properties":{"OBJECTID":598,"wlbNpdidWellbore":1078,"wlbName":"6507/7-9","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 6507/7-9 was drilled in the Northern\r\npart of the Haltenbanken area, near the crest of the Heidrun Field structure,\r\nat the proposed site for the production platform. The well was a pilot hole for\r\nthe Heidrun Field production wells. It should evaluate the top 150 m of\r\nsediments below seabed as foundation for the Heidrun Production Platform, and\r\nit should drill to 850 m RKB to ensure that the section to be penetrated by the\r\nconductors and surface pipes for all production wells, is free of shallow gas.\r\nA site survey had detected five shallow gas anomalies at 505, 558, 609, 708,\r\nand 762 m.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eAppraisal well 6507/7-9 was spudded with\r\nthe semi-submersible installation Treasure Hunter on 4 August 1987 and drilled\r\nto TD at 850 m in Pliocene sediments of the Naust Formation. No significant\r\nproblems were encountered during drilling. The well was drilled all through\r\nwith seawater and pre-hydrated bentonite and returns to the seabed. A sub-sea\r\ncamera was monitoring the wellhead area. \u003c/p\u003e\r\n\r\n\u003cp\u003eBoulders were encountered between 380 m\r\nand 400 m, but created no torquing problems while drilling. Wire line logs\r\nidentified sands at 600 to 612 m, at 695 to 698 m, and at 749 to 757 m. Gas\r\nbubbles were observed emanating from the wellhead while drilling the sand at\r\n600 - 612 m. The gas bubbles decreased after drilling the section and ceased\r\nwhile circulating seawater around to the seabed, indicating hydrostatic\r\npressure. The other sands produced no gas bubbles to surface, and none of the sands\r\nshowed any signs of high resistivity. It was concluded that shallow gas should\r\nnot be a problem in drilling future wells from the Heidrun Platform on this\r\nlocation, although shallow gas-filled sands in neighbouring locations could not\r\nbe excluded. \u003c/p\u003e\r\n\r\n\u003cp\u003eNo cores were cut and no wire line fluid\r\nsamples taken in this well.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 8\r\nAugust 1987 as a dry well\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"599","properties":{"OBJECTID":599,"wlbNpdidWellbore":1128,"wlbName":"34/10-32 R","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 34/10-32 R is a re-entry of well\r\n34/10-32 on the Gullfaks South structure. The objective of the re-entry was\r\ntesting and permanent abandonment.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 34/10-32 was re-entered with the\r\nsemi-submersible installation Deepsea Bergen on 15 July 1987. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAfter drill stem testing the well was\r\npermanently abandoned on 10 August as an oil and gas appraisal well.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eTesting\u003c/span\u003e\u003c/b\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eTwo DST tests were performed in the\r\nStatfjord Group.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eDST 1A tested the interval 3457 - 3471 m in\r\nthe Eirikson Formation. It produced 800 Sm3 gas and 280 m3 water /day through a\r\n7.1 mm choke. The gas gravity was 0.661(air = 1). The bottom hole temperature\r\nwas 128 °C.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eDST 2 in the interval 3368 - 3374 m in\r\nthe Nansen Formation. This test produced 1085 Sm3 oil, 157400 Sm3 gas, and 130\r\nm3 water /day through a 17.5 mm choke. The GOR was 145 Sm3/Sm3, the oil density\r\nwas 0.860 g/cm3, and the gas gravity was 0.639 (air = 1). The bottom hole\r\ntemperature was 129 °C. Maximum oil production in DST2, before water break-through,\r\nwas 2670 Sm3 oil/day through a 25.4 mm choke. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"600","properties":{"OBJECTID":600,"wlbNpdidWellbore":1131,"wlbName":"25/5-1 A","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eAppraisal well\r\n25/5-1 A was drilled as a sidetrack to well 25/5-1. The wells are located in\r\nthe Northern part of block 25/5 near the crest of a westward tilted Jurassic\r\nfault structure that straddles both block 25/5 and block 25/2.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe main purpose of\r\nthe well was to prove additional accumulation and if possible determine an\r\noil/water contact that might be compared with well 25/5-1. Also checking a\r\npossible spill point through the main fault mapped 4 km SSW of well 25/5-1.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eAppraisal well\r\n25/5-1A was spudded by Golar-Nor offshore a/s semi-submersible installation\r\nNordtrym 1 August 1987, and completed 16 September 1987 at a depth of 3432 in\r\nthe Early Jurassic Drake Formation. The Vestland Group came in at 3312 m\r\n(3050.9 m TVD MSL), 91.9 m TVD deeper than in 25/5-1 but with the same\r\nthickness as in 25/5-1. Top Dunlin Group / Drake Formation came in at 3403 m\r\n(3126.7 m TVD MSL). The whole reservoir was oil-saturated, confirming oil down\r\nto at least 3126.4 m TVD MSL, very close to the OWC that was estimated from the 25/5-1\r\npressure gradient data. However, a definite OWC was not observed. All in all\r\nthe well supported a total vertical oil column of 166 m as estimated from well\r\n25/5-1. The well was plugged and abandoned as an oil appraisal well.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test\r\nwas performed.\u003c/p\u003e\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"601","properties":{"OBJECTID":601,"wlbNpdidWellbore":1134,"wlbName":"6201/11-1","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 6201/11-1 was drilled on the Albert\r\nstructure as the first well on the Norwegian side of the Nordfjord Horst. The\r\nbest well for correlation is expected to be UK well 211/2-1 which was\r\nterminated in rocks of possibly Rhaetian age and was dry. The primary objective\r\nfor the well was to test the hydrocarbon potential in Triassic sandstones in\r\nthe A prospect. A secondary objective was to test the structural closure in the\r\nLista/Sele Formation and to acquire geological information related to remaining\r\nprospects in the block.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 6201/11-1 was spudded with\r\nthe Semi-submersible installation Deepsea Bergen on 13 August 1987 and drilled\r\nto TD at 3850 m in the Early Triassic Teist Formation. A 12 1/4" pilot\r\nhole was drilled with returns to seabed from 30" casing shoe to 930 m. The\r\nwell started flowing water. It was plugged back and cement was dressed to 650\r\nm. Opened to 26" hole and sat 20" casing already at 641 m. Possible\r\nsource of water flow was between 650 m to 719 m, but most likely a stronger\r\nsource was below 719 m. The 17 1/2" hole was drilled to 1808 m where the\r\nwell kicked due to rapid pore pressure increase near section TD. The well was\r\nplugged back and 13 3/8" casing set at 1735 m. At 3384 m there was a\r\nproblem with hole stability and drilling was stopped. It was decided to set\r\n7" liner. The well was drilled with seawater and bentonite down to 479 m,\r\nwith gypsum/PAC polymer mud from 479 m to 2701 m, and with gel/lignosulfonate\r\nmud from 3384 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eOil shows appeared in limestones already\r\nin the Hordaland Group at 1325 m down to 1725 m. From 1725 m in the Hordaland\r\nGroup to 1970 m in the Balder Formation oil shows was recorded on claystones.\r\nBelow 2000 m oil shows were recorded in sandstones. Top reservoir came in as\r\nprognosed at 2678 m and was hydrocarbon bearing. There were good oil shows on\r\ncores down to 2881 m, and the logs show possible oil satur","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"602","properties":{"OBJECTID":602,"wlbNpdidWellbore":1135,"wlbName":"9/2-2","wlbHistory":"\"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 9/2-2 was drilled on a\r\nfault-induced dome-formed structural trap (the Alpha structure) in the\r\nnorthwestern part of the block. The primary objective for the well was to test\r\nthe Jurassic sandstones of the Sandnes- and Bryne Formations in the structure.\r\nIn addition the well should test the structural and geophysical\r\ninterpretations, and improve the geological, geochemical and paleontological\r\nunderstanding of the area. The well was programmed and designed as a possible future\r\nproducer.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 9/2-2 was spudded with the\r\nsemi-submersible installation Ross Isle 8 august 1987 and drilled to TD at 3550\r\nm in the Triassic Skagerrak Formation. Drilling went on with some minor\r\nproblems in the interval 2400 - 3000 m. Inclination increased in the 8\r\n1/2" section towards TD and was 11.1° at 3539 m. The well was drilled with\r\nseawater and gel down to 363 m, with gypsum/polymer mud from 363 m to 2871 m,\r\nand with gel/lignosulphonate mud from 2871 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eTop Sandnes and Bryne sandstones were\r\nreached at 3131 m and 3230 m respectively. From the logs the Middle Jurassic\r\nsandstones were interpreted as water bearing. The results of the log\r\ninterpretation indicated some low hydrocarbon saturations in the lower part of\r\nthe Sandnes formation and in major parts of the Bryne formation. Some residual\r\nhydrocarbons may be present, but the major part of the hydrocarbon saturations,\r\nparticular in the Bryne formation, is unrealistic due to organic material and\r\ncoal layers affecting the logs. The first show in the well was recorded at 3114\r\nm and the deepest near TD at 3544 m. The shows were generally seen in shales\r\nand coals or in sandstones interbedded with shales and coals. The strongest and\r\nmost continuous shows were seen in shales from 3114 m to 3234 m (base Egersund\r\nFormation - upper Sandnes Formation), and in interbedded sands, shales, and\r\ncoals in the interval 3417 m to 3498 m (base Bryne Formation and","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"603","properties":{"OBJECTID":603,"wlbNpdidWellbore":1136,"wlbName":"6406/8-1","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eBlock 6406/8 is located on the\r\nHaltenbanken offshore Mid-Norway, in the southwestern corner of the Halten\r\nTerrace, approximately 215 km west north west of Trondheim. The primary\r\nobjective of exploration well 6406/8-1 was to test the hydrocarbon potential in\r\nthe Middle Jurassic Fangst group and the Lower Jurassic Båt group (Ror and\r\nTilje formations). Possible intra-Cretaceous sands related to a seismic marker\r\nwere considered as second target. Well 6406/8-1 was the first well drilled on\r\nthe licence. It is located on a domal structure at the Base Cretaceous\r\nUnconformity. The prognosed TD for the well was 5027 m.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 6406/8-1 was spudded with the\r\nsemi-submersible installation SSDV Vinni on 15 September 1987 and drilled to\r\nfinal TD at 4914 m in the Early Jurassic Åre Formation. The well was drilled\r\nwater based.\u003c/p\u003e\r\n\r\n\u003cp\u003eIt was drilled initially to a total depth\r\nof 4942 m where it had penetrated the Fangst Group. The well kicked and the\r\ndrill string was lost in the hole. Due to incomplete fishing operation a\r\nsidetracked well was drilled. The sidetrack was spudded on 22 January 1988 at\r\n4262 m. The Fangst Group was once again penetrated and an intermediate logging\r\nwas performed. Drilling commenced to 4914 m. Due to hazardous drilling with\r\ngains and stuck pipe it was agreed that 4914 m was to become the TD of this\r\nwell. A final logging operation was made comprising FMT and RFT. The Fangst\r\nGroup down to top Ile Formation was interpreted from data available from the\r\nfirst hole. Due to failed MWD and no wire line logs below 4500 m in the first\r\nhole the Båt Group is interpreted from the sidetrack. Horner corrected wire\r\nline log BHTs at TD gave a formation temperature of 172 deg C. \u003c/p\u003e\r\n\r\n\u003cp\u003eSome gas dissolved in water was tested in\r\nthe Ile Formation; otherwise no moveable hydrocarbons were seen in the well.\r\nDull yellow spots and weak pale green cut fluorescence was described on\r\nsandstone from 3145 to 3190 m. Dull orange","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"604","properties":{"OBJECTID":604,"wlbNpdidWellbore":1138,"wlbName":"7219/9-1","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 7219/9-1 is located in the Bjørnøya\r\nSør area between the Veslemøy High and the Polheim Sub-platform. The main\r\ntarget in the well was the reservoir and hydrocarbon potential of Early-Middle\r\nJurassic sandstones. Late Triassic sandstone of the Snadd Formation was a\r\nsecondary target. The wildcat well should also provide good seismic tie and\r\ngain velocity information to enable more detailed mapping of the area. It\r\nshould further provide maximum amounts of information on source, seal and\r\nreservoir intervals. The well was positioned to leave a minimum of untested\r\nreserves up-dip with respect to the primary objective.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 7219/9-1 was spudded with\r\nthe semi-submersible installation Polar Pioneer on 17 November 1987 and drilled\r\nto TD at 4300 m in the Triassic Snadd Formation. The hole was drilled without\r\nriser to the 20" casing depth. It was drilled to 1625 m without problems\r\nwhen loss of drilling mud occurred. The hole was stabilised, logged, sidewall\r\ncores were cut, and it was cemented. During cementing there were problems in\r\nthe top hole with the BOP and permanent guide base. Upper part of the 30"\r\nsection was cemented. Coring equipment did not get past dog leg at 2208 m.\r\nAttempts to open the hole were made but the equipment got stuck. Fishing was\r\nunsuccessful. A cement plug was set from 2185 m to 2004 m, and the hole was\r\nsidetracked at ca 2078 m. Further drilling to TD went without significant\r\nproblems. The well was drilled with seawater and hi-vis pills down to 718 m and\r\nwith KCl / polymer mud from 718 m to 2723 m. From 2723 m the KCl was allowed to\r\ndeplete naturally and the well was drilled with a polymer mud to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eTop reservoir, Stø Formation, was\r\nencountered from 1950.5 m to 2062 m with 99 m net sand of 17.8% average\r\nporosity. Nordmela Formation was penetrated from 2062 m to 2205.5 m with 59.5 m\r\nnet sand with 16.5 % average porosity. The Tubåen Formation from 2205.5 m to\r\n2305 m ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"605","properties":{"OBJECTID":605,"wlbNpdidWellbore":1140,"wlbName":"7122/6-1","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 7122/6-1 was designed to\r\ndrill a prospect located in the central part of the block, located in the\r\neastern part of the Hammerfest Basin. The purpose of well 7122/6-1 was to test\r\nthe hydrocarbon potential of the Middle Jurassic to Upper Triassic sandstones\r\nin the main structure of the block.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 7122/6-1 was spudded with\r\nPolar Frontier Drilling semi-submersible installation Polar Pioneer on 6\r\nSeptember 1987 and drilled to TD at 2707 m in the Middle - Late Triassic Snadd\r\nFormation.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe structure penetrated by the well is a\r\nlarge tilted block dipping southwards. The northern closure is a major WNW-ESE\r\nfault. Top of the main markers were encountered higher than prognosed: top Stø\r\nFormation came in 71 m higher, and top Trias came in 183 m higher than\r\nexpected. The Jurassic reservoirs were found water bearing, however, some oil\r\nrecovered by RFT indicated the presence of a thin (1.5 m) oil zone at the top\r\nof the Stø formation. The late Triassic Snadd Formation proved gas and\r\ncondensate in a 71.5 m gross thickness reservoir. Weak shows were recorded in\r\ncuttings from the Hekkingen shale. Strong whitish yellow direct fluorescence\r\nwas observed in the cored sandstones all through the Stø Formation down to 2040\r\nm. Weak shows were recorded on the cored sandstones in the Nordmela, Tubåen,\r\nand Fruholmen Formations. Below this level, in the Triassic section, weak oil\r\nshows were recorded in sandstones, including the reservoir section between 2400\r\nto 2450 m that produced gas and condensate in the DST.\u003c/p\u003e\r\n\r\n\u003cp\u003eA very dense geochemical screening in\r\nthis well showed only very lean source rocks (< 1% TOC) above 1340 m.\r\nBetween 1340 m and 1931 m, the average TOC is around 1% with a somewhat richer\r\ninterval between 1750 m and 1900 m (TOC 1.5 to 3%), but with HI generally lower\r\nthan 100 mg/g. Between 1931 m and 2015 m, high organic content (TOC 10 to 15%)\r\nand high HI (280 - 350 mg/g) indicate a very","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"606","properties":{"OBJECTID":606,"wlbNpdidWellbore":1173,"wlbName":"6406/3-4","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 6406/3-4 was drilled to appraise\r\nthe Trestakk oil discovery made with well 6406/3-2. The primary purpose of the\r\nwell was to appraise hydrocarbon accumulations of significant amounts in the\r\nMiddle Jurassic reservoirs down flanks on the Trestakk structure. Secondary\r\nobjectives were to check for hydrocarbon accumulations deeper than the\r\nstructural closure of the main field, to verify the geophysical and structural\r\ninterpretation, and improve the geological, paleontological and geochemical\r\nunderstanding of the area. Total depth was to be 50 m into the Ti1je Formation.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eAppraisal well 6406/3-4 was spudded with\r\nthe Dyvi Offshore semi-submersible installation Dyvi Delta on 25 September 1987\r\nand drilled to TD at 4414 m in Early Jurassic Tilje Formation. The well was\r\ndrilled with seawater and hi-vis pills down to 1179 m, with gypsum/polymer mud\r\nfrom 1179 m to 3984 m, and with gel/lignosulphonate mud from 3984 m to TD.\r\nDrilling proceeded without significant problems and there were no signs of\r\nshallow gas. An expected pressure build-up started in Paleocene and reached its\r\nmaximum at 1.50 g/cm3 EMV in the top of Cretaceous. After this the\r\nover-pressure decreased and was at 1.42 g/cm3 EMV close to top Jurassic.\u003c/p\u003e\r\n\r\n\u003cp\u003eA very weak show was recorded in\r\nassociation with a 2.61% gas peak at 2469 m in the Springar Formation. From\r\n2450 m in the Nise Formation to 2670 m shows were recorded on 50 % of sandstone\r\nsamples. These shows appeared to be a volatile, light petroleum and continued,\r\ngradually disappearing, down to 2750 m in the Nise Formation. Top reservoir\r\ncame in at 4018 m. There were good shows on cores down to 4078 m, but the\r\nreservoir qualities did not seem to be very good due to low permeability. In\r\nthe Ile Formation poor shows were recorded on cores, indicating tight rocks or\r\nresidual oil. Residual shows were recorded also in the Tofte Formation, while\r\nweak "background" shows were recorded in the Tilje","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"607","properties":{"OBJECTID":607,"wlbNpdidWellbore":1174,"wlbName":"6407/5-1","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 6407/5-1 was situated in Gimsan\r\nBasin, on the eastern limits of the Halten Terrace adjacent to the Trøndelag\r\nPlatform. The primary target for the well was an Early Cretaceous stratigraphic\r\nplay, which had been interpreted seismically as a submarine fan deposit.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 6407/5-1 was spudded with\r\nWilh. Wilhelmsen A/S semi-submersible rig Treasure Scout on 11 December 1987\r\nand drilled to TD at 4306 m in the Middle Jurassic Garn Formation. The well was\r\ndrilled with seawater and hi-vis pills down to 1025 m, with\r\nseawater/gel/lignosulphonate mud from 1025 m to 2053, and with seawater/polymer\r\nmud from 2053 m to TD.á Drilling proceeded without significant problems. No\r\nshallow gas was encountered. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe well penetrated the Early Cretaceous\r\nat 2920.5 m, (prognosed at 2980 m) and a thick argillaceous sequence was\r\ndrilled. There were no indications of sand in Early Cretaceous, or in Late\r\nJurassic. Seismics showed a wedge (the prospect), but there was no sand present.\r\nAn exotic section of Early Cretaceous and Late Jurassic claystones is present\r\nwithin the Early Cretaceous over the interval 3605 m to 3655 m. The logs showed\r\ntwo well-defined hot shales that have not been observed before. This section\r\nwas interpreted as a displaced gravity slide block. The Early Cretaceous\r\nsediments below consist of argillaceous lithologies, again with no reservoir\r\ndevelopment. \u003c/p\u003e\r\n\r\n\u003cp\u003eMinor weak shows occurred in thin\r\nsandstone units over the interval 2370 to 2600 m in the Lange Formation. Weak\r\nshows were also recorded in the shales of the displaced slide block, in the\r\nSpekk Formation, and in the Melke Formation. The sandstones of the Garn\r\nFormation also had weak shows, but without visible stain. The Garn sandstones\r\nhad porosity less than 6 %, and there were no noticed closures at Garn level.\r\nThe Late Jurassic Spekk shales showed good development in the well position\r\nwith a thickness of 247 m, and geochemical analyses s","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"608","properties":{"OBJECTID":608,"wlbNpdidWellbore":1176,"wlbName":"34/7-11","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 34/7-11 is located in the Tampen\r\nSpur area in the Northern North Sea. Its overall purpose was to assess the\r\nhydrocarbon potential in the "B"-structure in the southern part of\r\nthe block. The primary objectives were to establish the thickness and reservoir\r\nquality of the prospective Brent the Brent Group in Group, and to determine the\r\nOWC. The secondary objectives were to assess the potential of the Dunlin Cook\r\nFormation reservoir, the Statfjord Formation and the upper part of the Triassic\r\nLunde unit B/C reservoir section. TD was prognosed to 2900 m.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell was spudded with the semi-submersible\r\ninstallation Treasure Saga on 2 October 1987. The well was drilled through the\r\nPliocene Late Miocene Nordland Group, and terminated at a depth of 861 m for\r\ntechnical reasons. The well was drilled with spud mud from top to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eNo cores were cut and no wire line fluid\r\nsamples were taken.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 11 October  1987 as a junk well.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was performed.\u003c/p\u003e\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"609","properties":{"OBJECTID":609,"wlbNpdidWellbore":1177,"wlbName":"7226/11-1","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eExploration well 7226/11-1 is located on\r\nthe Norsel High in the southeastern part of the Bjarmeland Platform area, close to the\r\nsouthwestern margin of the Nordkapp Basin. The well was designed to test Early\r\nJurassic/Late Triassic sandstones, Base Anisian sandstones and Permian\r\ncarbonates. The well should also test the geophysical and structural\r\ninterpretation and improve the geological, geochemical and paleontological\r\nunderstanding of this new area in the Barents Sea. Planned TD was 4620 m,\r\npenetrating the Early Permian Unconformity.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well is Reference Well for the Ulv,\r\nPolarrev, and Ørn formations.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 7226/11-1 was spudded with\r\nthe semi-submersible rig Ross Rig 22. October 1987 and drilled to TD at 5200 m\r\nin metamorphic basement rocks. A 9 7/8" pilot hole was drilled to 720 m\r\nwithout a riser. During opening of the pilot hole to 26" hole, an angle of\r\n5° was built up at approximately 500 m and a new hole was drilled next to the 9\r\n7/8" pilot hole. The 20" casing shoe was set at 698 m. Severe\r\nproblems were experienced in the 12 1/4" section with four twist-offs (3\r\ntimes core barrel and once jar). There was no shallow gas in the hole. The well\r\nwas drilled with seawater and hi-vis pills down to 702 m, with gypsum / polymer\r\nmud from 702 m to 2515 m, and with gel / lignosulphonate mud from 2515 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eA thin (34 m) Early Jurassic Tubåen\r\nFormation sandstone was encountered at 1202 m, 19 m higher than expected.\r\nDrilling data and logs indicated that this reservoir was water bearing. In the\r\nLate Triassic Fruholmen Formation only 12.3 % net sand with an average 17.7 %\r\nporosity was estimated. Expected bottom Anisian sandstone reservoir at 2330 m\r\nwas not developed as good as expected. Only thin sandstone stringers were encountered\r\nbetween 2280 m to 2310 m without good indications of hydrocarbons. It was\r\ndrilled to 2913 m where a sudden increase in drilling velocit","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"610","properties":{"OBJECTID":610,"wlbNpdidWellbore":1178,"wlbName":"25/2-10 SR","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 25/2-10 S was\r\ndesigned to drill the Gamma Structure, one of the Frigg satellites, east of the\r\nEast Frigg Beta Structure. The primary objective of the well was to test\r\nwhether the gamma structure is an eastward extension of the East Frigg Beta\r\nstructure. The main target was the Lower Eocene Frigg Formation; secondary\r\ntargets were the Balder and Ekofisk Formations. In addition a possible gas\r\naccumulation was expected in a thin sand body of late Oligocene age. \u003c/p\u003e\r\n\r\n\u003cp\u003eShallow gas indications\r\nat 256 m MSL, and a disturbed zone on the seismic from seabed to the Frigg\r\nFormation demanded a deviated well in order to reach the Frigg Formation at its\r\nhighest structural position.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eAppraisal well\r\n25/2-10 S was spudded 2 December 1985 by Sonat Offshore A/S semi-submersible\r\nrig Henry Goodrich. The well terminated in Limestone of the Early Paleocene Ekofisk\r\nFormation at a depth of 2967 m (2643 m TVD RKB).\u003c/p\u003e\r\n\r\n\u003cp\u003eDue to shallow gas\r\nindication on the chosen locality, the well was spudded 1100 m north and 200 m\r\neast of the TD position. Drilling proceeded without significant problems down\r\nto 1049 m here mud was lost. \u003c/p\u003e\r\n\r\n\u003cp\u003eAn Oligocene sand, now re-datated to be of Lower Miocene age, was\r\nconfirmed in the interval 1115 m to 1148.5 m (1006.5 m to 1031 m TVD RKB) with\r\ngas from top sand at 1115 m down to a GOW at 1136.5 m (1006.5 m ? 1022.5 m TVD\r\nRKB). From 1095 m to 1150 m (992 m to 1030 m TVD RKB) strong yellowish green to\r\nyellow ocher direct fluorescence and milky yellow cut were observed on cuttings\r\nand SWC. Pressure measurements suggest an oil gradient of ca 0.72 g/cc below\r\nthe gas with a tentative OWC at 1162 m (1041.5 m TVD RKB). Top Frigg Formation\r\ncame in at 2230 m (1943 m TVD RKB) with minor amounts of oil and gas. The GOC\r\nin the Frigg reservoir was found at 2243.6 m (1956 m TVD RKB) and the OWC at 2259.6\r\nm (1971 m TVD RKB). Brown oil staining was reported on the cores from 2243.5 m\r\nto 2257 m. In the Frigg For","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"611","properties":{"OBJECTID":611,"wlbNpdidWellbore":1186,"wlbName":"34/10-3 R","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 34/10-3 R is a re-entry of well\r\n34/10-3, drilled in the Delta area in block 34/10\u003c/span\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003cspan\r\nlang=EN-US\u003ein the Northern North Sea in 1979\u003c/span\u003e\u003cspan lang=EN-GB\u003e. The\r\npurpose of the re-entry was plugging and permanent abandonment.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 34/10-3 was re-entered with the\r\nsemi-submersible installation Ross Isle on 3 October 1987.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was plugged and the well was permanently\r\nabandoned on 10 October 1987.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eTesting\u003c/span\u003e\u003c/b\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo drill stem test was performed.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"612","properties":{"OBJECTID":612,"wlbNpdidWellbore":1187,"wlbName":"34/7-12","wlbHistory":"\r\n\u003e\r\n\r\n\u003cp\u003eWell 34/7-12 is a replacement well for\r\nwell 34/7-11, which was junked for technical reasons. It is located in the\r\nTampen Spur area in the Northern North Sea. Its overall purpose was to assess\r\nthe hydrocarbon potential in the "B"-structure in the southern part\r\nof the block. The primary objectives were to establish the thickness and\r\nreservoir quality of the prospective Brent the Brent Group in Group, and to determine\r\nthe OWC. The secondary objectives were to assess the potential of the Dunlin\r\nCook Formation reservoir, the Statfjord Formation and the upper part of the\r\nTriassic Lunde unit B/C reservoir section. TD was prognosed to 2900 m.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 34/7-12 was spudded 20 m\r\nnorth of the 34/7-11 location. It was drilled with the semi-submersible\r\ninstallation Treasure Saga on 11 October 1987 and drilled to TD at 2784 m in\r\nthe Late Triassic Lunde Formation. The well was drilled without significant\r\ntechnical problems. The well was drilled with spud mud down to 852 m and with\r\nKCl mud from 852 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe Brent Group came in at 2169 m, and\r\nStatfjord Formation at 2606 m. Lunde Formation was encountered at 2763 m.\r\nOil/water contact was defined in the Ness Formation at 2250 m.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe Brent Group, from 2169 to 2340.5 m\r\n(171.5 m thick) comprised the sandy Tarbert Formation,the interbedded shaly and sandy Ness Formation, the sandy Etive and\r\nRannoch Formations and at the base the conglomeratic Broom Formation. The\r\nDunlin Group was penetrated from 2340.5 to 2606 m (265.5 m thick), comprising\r\nthe shaly Drake Formation at the top, the Cook Formation with interbedded\r\nsandstone and claystone, the Burton Formation with claystone and minor\r\nsandstone and the Amundsen and Calcareous Amundsen Formations having clay\r\nstones with minor limestone. The Statfjord Formation, 157 m thick from 2606 to\r\n2763 m, was dominated by sandstones with minor to interbedded claystone. The\r\nLate Triassic upper Lunde Formation was encountered at 2763 ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"613","properties":{"OBJECTID":613,"wlbNpdidWellbore":1188,"wlbName":"2/2-4","wlbHistory":"\r\n\r\n\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 2/2-4 was drilled on the northern\r\nsegment of the Alpha structure in the southeastern corner of block 2/2 on the\r\nnortheastern flank of the Central Graben in the Ula-Gyda Fault zone. The\r\nstructure is a salt induced dome in an area exposed to extensional tectonism\r\nwhere rollover mechanism may have influenced the final structure. The southern\r\nsegment well 2/2-1, separated from the northern by a normal fault, proved gas\r\nin Oligocene and oil in Late Jurassic sandstones. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe main objective of the well was to\r\ntest the reservoir potential of Late Jurassic Ula Sandstone and to test a\r\npossible communication with the Alpha South structure. If hydrocarbon bearing,\r\nthe objective was to prove an oil column thick enough for commercial exploitation\r\nof the Alpha structure.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 2/2-4 was spudded with Wilh.\r\nWilhelmsen semi-submersible rig Treasure Saga on16 April 1988 and drilled to TD\r\nat 4020 m in the Triassic Smith Bank Formation. The well was drilled with spud\r\nmud down to 915 m, with KCl mud from 915 m to 3310 m, and with gel mud from\r\n3310 m to TD. It was drilled down to top Jurassic and 9 5/8" casing was\r\nset. \u003c/p\u003e\r\n\r\n\u003cp\u003eOligocene came in at 2084 m with sand\r\nwith small amounts of gas. Eight pressure points in the interval gave a water\r\ngradient of 1.0 g/cc and a gas gradient of 0.21 g/cc. The gas/water contact was\r\ndefined at 2110.5 m, the same as in 2/2-1. Estimated porosity from logs was\r\nmax. 27%. The main target Ula reservoir was encountered at 3324 m, but was\r\nfound water wet. Only residual oil was found in the uppermost part of the Ula\r\nsandstone and in siltstone of the Bryne Formation. No cores were cut. One FMT\r\nsegregated sample recovered gas from 2109 m in Oligocene. The gas was very dry\r\nwith 97% methane. The well was abandoned on 7 June 1988 as a gas appraisal\r\nwell.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was performed\u003c/p\u003e\r\n\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"614","properties":{"OBJECTID":614,"wlbNpdidWellbore":1216,"wlbName":"6506/11-1","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 6506/11-1 was designed to prove\r\nhydrocarbons in the G-structure in the easternmost part of block 6506/11 close\r\nto Smørbukk Field. The primary purpose of the well was to prove significant\r\nhydrocarbon accumulations in the Middle-Early Jurassic reservoirs. Secondary\r\ntargets were sands of Cretaceous age, especially the Lysing Formation that has\r\nbeen proven to be oil-bearing in the area. The well should also test the\r\nhypothesis of a western ultra-high pore pressure area, verify the geophysical\r\nand structural interpretation and to improve the geological, paleontological,\r\nand geochemical understanding of the area. Total depth was planned 200 m into\r\nthe coal-bearing Åre Formation.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 6506/11-1 was spudded with\r\nSmedvig Drilling semi-submersible installation Dyvi Delta on 30 December 1987\r\nand drilled to TD at 4679 m in the Early Jurassic Åre Formation. The well was\r\ndrilled with spud mud down to590 m, with gypsum/polymer mud from 590 m to 3500\r\nm, and with Ligno/Lignite/Gel mud from 3500 m to TD. Shallow gas was present\r\nbetween 613 m and 618 m. The drilling generally went without problems. The\r\nLysing Formation sandstone was thinner than expected in this location. It was\r\nwater bearing with weak shows only. In the lower part of the Lange Formation an\r\n85 m sequence of sandstone with poor porosity and interbedded claystones was\r\nencountered.\u00A0 Weak shows were recorded in the sandstones and the sequence\r\nproved to be gas-bearing.\u00A0 The Fangst Group prospect came in as prognosed, but\r\ndid not indicate hydrocarbons except for poor to fair shows. Logs showed that\r\nit was water-bearing. High pressure was registered. This is typical for\r\nwater-bearing holes on Haltenbanken. Four cores were cut in the well; two in\r\nthe Garn Formation from 4140 m to 4195 m; one in the Ile Formation in the\r\ninterval 4262 m to 4274 m; and one core in the Ror/Tilje Formations from 4477 m\r\nto 4504 m. No wire line fluid samples were taken. The well","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"615","properties":{"OBJECTID":615,"wlbNpdidWellbore":1219,"wlbName":"25/1-10","wlbHistory":"\r\n\r\n\r\n\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 25/1-10 was drilled on the northern\r\npart of the Frigg Field in the Viking Graben. The primary objective was to test\r\nthe Mesozoic "Deep Frigg" structure below the Frigg Field. The\r\nstructure is a narrow north-south trending rotated mesozoic fault block. The\r\nfirst well drilled on the structure, 25/1-1, penetrated the top of Middle\r\nJurassic sandstones at more than 4500 m, but was abandoned due to water flow\r\nassociated with high pressure. The second well, 30/10-5, encountered both\r\nMiddle Jurassic Brent Group sandstones and Lower Jurassic Statfjord Group\r\nsandstones, but the sandstones were water bearing. Well 25/1-10 was designed to\r\ntest the remaining up dip potential of the Brent and Statfjord reservoirs.\r\nSecondary objectives were to establish the sweeping status of the Lower Eocene\r\nFrigg Formation and to obtain additional petrophysical data from this\r\nreservoir.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 25/1-10 was spudded with the\r\nsemi-submersible installation Vinni on 19 April 1988 and drilled to TD at 3739\r\nm in the Middle Jurassic Brent Group. The interval 287-923 m was drilled with a\r\n14 3/4" pilot hole to check for shallow gas. No gas was detected during\r\ndrilling. The main problems during operations were encountered with the shales\r\nabove the Frigg Formation and subsequent mud losses into the Frigg Formation.\r\nFurther hole problems and mud losses occurred in the Brent Group, related to\r\nhigh pressures and fragile formation. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eTop of Frigg was found at 1926 m. The\r\nelectrical wireline logs clearly showed that formation water has swept the gas\r\nthat was initially present in the Frigg reservoir sands. Quantitative analysis indicate\r\naverage porosities of 29 - 30 % and a residual gas saturation of 19 %. The well\r\npen","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"616","properties":{"OBJECTID":616,"wlbNpdidWellbore":1224,"wlbName":"2/8-11","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 2/8-11 was drilled as a field\r\ndelineation well intended to help establish the commerciality of the southern\r\nNorth Sea Valhall Field, which was discovered by well 2/8-6 and confirmed by\r\nwells 2/8-8, 2/8-9 and 2/8-10. The primary objective was to test the Late\r\nCretaceous chalk reservoirs and to estimate the presence of hydrocarbons. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 2/8-11was spudded with the\r\nsemi-submersible installation Ross Rig on 10 August 1976 and drilled to TD at 2655\r\nm in the Early Cretaceous Rødby Formation. The well was drilled in a total of\r\n33 days without any major drilling problems. However, 13 days were spend on\r\nlogging in the 12 1/4-inch hole and setting and cementing two completion\r\nstrings comprising of a 7-inch liner cemented inside the 9 5/8-inch casing. The\r\nwell was drilled with seawater/bentonite/caustic soda down to 381 m, with\r\nDrispac/Dextrid/lignosulphonate mud from 381 m to 1294 m, and with\r\nDrispac/Dextrid/lignosulphonate/Soltex mud from 1294 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well penetrated a normal\r\nQuarternary-Tertiary sequence with the top Paleocene Ash Marker at 2437 m, 51m\r\nlower than predicted. The Late Cretaceous Maastrichtian chalk (Tor Formation) was\r\nencountered at 2468 m with a total thickness of 15 m and with an oil column of\r\nthe same magnitude. The porosity was 40-50% and the water saturation close to\r\nzero. The two Coniacian-Turonian reservoirs, (upper and lower Hod Formation)\r\nhad porosities of 30-40% and water saturations averaging 50% with 18.5 m pay in\r\nthe upper reservoir and 33.5 m pay in the lower reservoir. The Turonian shale\r\nwas penetrated at 2612 m and the top of the Early Cretaceous was reached at\r\n2624 m giving a total chalk thickness of 144 m.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003e","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"617","properties":{"OBJECTID":617,"wlbNpdidWellbore":1225,"wlbName":"30/6-22","wlbHistory":"\r\n\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 30/6-22 was drilled on the 30/6-19 Beta\r\nSaddle Discovery between the Veslefrikk field and the 30/6-5 Oseberg East (Beta\r\nSouth) discovery. The discovery well 30/6-19 found oil in the Brent Group. The\r\nobjectives of well 30/6-22 were to narrow the range in the oil/water contact\r\nlevels in the Tarbert/Ness and the Etive/Rannoch/Oseberg Formations and to get\r\ninformation about lateral variation in reservoir quality.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 30/6 22 was spudded 21 May\r\n1988 by Polar Frontier Drilling semi submersible rig Polar Pioneer and drilled\r\nto TD at 3336 m in the Late Jurassic Statfjord Group. Drilling went without\r\nproblems, but the prospect was intersected 50 m away from where it was decided,\r\nin north-eastern direction. The well was drilled with spud mud down to 963 m\r\nand with KCl/polymer mud from 963 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eTop Brent Group, Tarbert Formation was\r\npenetrated at 2874 m. Moveable oil was confirmed by logs, RFT pressure\r\ngradients and tests in sandstones in the Ness and Etive formations from 2908 m\r\n(2880 m TVD MSL). The OWC was not clearly defined, but indicated from RFT\r\npressure gradients to be at 2935 m (2907 m TVD MSL). The Oseberg Formation was\r\nwater bearing. The Cook Formation had good oil shows but it was tight and\r\nimpossible to test. No shows were recorded in the Statfjord Formation.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eSix cores were cut in the well: The Brent\r\nGroup was cored in five cores in the interval 2854 - 3009.9 m and one core was\r\ncut in the Cook Formation in the interval 3122.5 - 3150.4 m. RFT-tests\r\nindicated oil from 2910 m (Ness Formation) and mud filtrate from 2934 m (Etive\r\nFormation).\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was suspended on 13 July as an\r\no","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"618","properties":{"OBJECTID":618,"wlbNpdidWellbore":1226,"wlbName":"33/9-14","wlbHistory":"\r\n\r\n\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 33/9-14 was drilled on the Statfjord\r\nNord Field on Tampen Spur in the North Sea. The primary objective of the well\r\nwas to verify the lateral and vertical distribution of sand within a thick\r\nVolgian sequence and to prove oil below 2690 m MSL in this sequence (deepest\r\noil in Volgian, well 33/9-8). The Brent Group was a secondary target.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 33/9-14 was spudded with\r\nthe semi-submersible installation Deepsea Bergen and drilled to TD at 2982 m in\r\nthe Early Jurassic Drake Formation. There were signs of shallow gas from 408\r\n409 m, but the gas bearing sands created no problems. No significant problem\r\nwas encountered in the operations. The well was drilled with seawater/gel down\r\nto 414 m, with gypsum/polymer mud from 414 m to 2670 m, and with\r\ngel/lignosulphonate mud from 2670 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe reservoir (interpreted as Kimmeridgian\r\nage Intra Draupne Formation Sandstone) came in as prognosed at 2674 m. The\r\noil/water contact was taken from the logs to be at 2747 m, while pressure\r\ngradients suggest the contact could be five meter higher up. Intermittent weak\r\nshows were described down to 2800 m, else no shows were described in the well. \u00A0The\r\nreservoir properties were very good with porosities up to 30 %. The Brent\r\nGroup, Ness Formation came in at 2777 m. It was water wet.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eSix cores were cut in the Intra Draupne\r\nFormation Sandstones and the Brent Group in the interval 2680 to 2879 m. The\r\nrecovery was generally good except for core 3, for which only 0.5 m was recovered.\r\nThe core-log depth shift was 3.0 to -3.5 m for all cores. FMT fluid samples\r\nwere taken at 2757 m and at 2798.4 m.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was permane","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"619","properties":{"OBJECTID":619,"wlbNpdidWellbore":1227,"wlbName":"6406/3-5","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 6406/3-5 was designed to explore\r\nthe Lambda structure and was the first well on the structure. The Lambda\r\nstructure is a flat-lying horst situated in the NE corner of the block.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe primary purpose of the well was to\r\nfind hydrocarbon accumulations of significant amounts in the Middle and Lower\r\nJurassic sandstones of the Fangst Group and Tilje Formation. Secondary\r\nobjectives were to verify the interpretation regarding the structural closure\r\ntowards north, and to verify the geophysical and structural interpretation and\r\nimprove the geological, paleontological and geochemical understanding of the\r\narea. The well was planned to TD in the Åre Formation.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 6406/3-5 was spudded with\r\nSmedvig Drilling semi-submersible rig West Delta on 3 April 1988 and drilled to\r\na total depth of 4283 m in the Early Jurassic Tilje Formation. Shallow gas was\r\nregistered at 570 m. After pulling out to cement this zone, it was impossible\r\nto get back into the hole again. After a new spud 3 May, the 30" was set\r\nat 418 m, and 20" at 538 m. A new shallow gas zone was registered at 813\r\nm, and the mud was weighted to 1.35 g/cm. The circulation was lost at 1116 m,\r\nand the section was cemented. After this drilling progressed with a mud weight\r\nof 1.25 g/cm3. This resulted in lost circulation at 1340 m. Both times it was\r\nassumed that that the circulation was lost in the zone around 562 m. The hole\r\nwas cemented back and drilled to 607 m where a new leak-off test up to 1.34\r\ng/cm was performed. This time there were no problems with the drilling to 1749\r\nm (setting depth of 9 5/8" casing) with mud weight of 1.25 g/CM3. Further\r\ndrilling to TD proceeded without significant problems. The well was drilled\r\nwith spud mud down to 545 m, with gypsum/polymer mud from 545 m to 3841 m, and\r\nwith gel/lignite/lignosulphonate mud from 3841 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eTop Fangst was encountered at 3817 m.\r\nThere were weak shows in the top ten","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"620","properties":{"OBJECTID":620,"wlbNpdidWellbore":1229,"wlbName":"6407/7-3","wlbHistory":"\r\n\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 6407/7-3 was drilled on the northern\r\npart of the A structure of the Njord Field. The main objectives of the well\r\nwere to test the hydrocarbon potential of the Ile Formation, to test the\r\nhydrocarbon potential of the Tilje Formation above the oil down to level in the\r\nTilje Formation in well 6407/7-1, and to obtain formation pressure data to\r\nindicate the relationship between the A-north and the A-east/A-central\r\ncompartments.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 6407/7-3 was spudded with the\r\nsemi-submersible installation Polar Pioneer on 3 March 1988 and drilled to TD\r\nat 3222 m in the Triassic Grey Beds. At 891 m, after setting of 30"\r\ncasing, gas started to stream out of the casing. It was assumed that the gas\r\ncame from the bottom of the hole, since there were no previous peaks on the MWD\r\nlog. Three cement plugs were set in the interval 780 - 891 m, but the gas\r\ncontinued to stream. A plug was then set in the interval 510 - 570 m, and the\r\ngas stream decreased. The hole was drilled up again to 525 m, where 20"\r\ncasing was set, originally not a part of the program. Two zones had shallow\r\ngas, 553 - 570 m and 652 - 685 m, which was in agreement with what was assumed\r\nin the site survey. Further drilling proceeded without any significant\r\nproblems. The well was drilled with spud mud down to 536 m, with gel and\r\nseawater from 536 m to 1098 m, with Newdrill/KCl/PAC from 1098 m to 3048 m, and\r\nwith Newdrill/PAC.\u003c/p\u003e\r\n\r\n\u003cp\u003eTop Jurassic was encountered at 2795 with\r\na 12 m thick Spekk Formation overlying the Middle Jurassic Not Formation. Top\r\nof the reservoir sections was encountered at 2851 m. Light oil was encountered\r\nin two differently pressured reservoir zones. The upper reservoir was the Ile\r\nFormation from 2851 to 2867 m with a net pay of 10.8 m. The lower reservoir was\r\nthe Tilje Formation and into the Åre Formation. The oil bearing interval was\r\nfrom 2936.5 m and down to siltstones at 3068 m with a total net pay of 50.4 m. The\r\nÅre Format","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"621","properties":{"OBJECTID":621,"wlbNpdidWellbore":1233,"wlbName":"34/7-13","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 34/7-13 was drilled in the north\r\nwestern part of block 34/7 on the Snorre West prospect. The prospect is divided\r\ninto two main fault segments by a SW NE trending fault with a throw of 60 m. The\r\nwell was located in the southern part of the two segments. The primary purposes\r\nof the well were to explore the Snorre West prospect and to test a possible\r\nextension of the Statfjord East Field in a northward direction. The main target\r\nof the well was sandstones of the Middle Jurassic Brent Group. Secondary target\r\nwas sandstones of the Early Jurassic Statfjord Formation.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 34/7-13 was spudded with the\r\nsemi-submersible installation Treasure Saga on 19 February 1988 and drilled to TD at 2994 m in the Late Triassic Lunde Formation. Drilling proceeded without\r\nsignificant problems, but up to 21 deg deviation in the deepest section of the\r\nwell caused 11 m deviation between MD and TVD at TD. Shallow gas was\r\nencountered at 459 m, but it did not cause any technical problems. The well was\r\ndrilled with spud mud down to 434, with Gel mud from 434 m to 973 m, with KCl\r\nmud from 973 m to 2682 m, and with gel mud from 2682 m to TD. \u003c/p\u003e\r\n\r\n\u003cp\u003eAbove the Jurassic the well penetrated\r\nmainly claystones with the exception of the Utsira Formation and some sandstone\r\nintervals between 1265 and 1325 m in the Hordaland Group. The Jurassic\r\ncomprised the Middle Jurassic Brent Group, and the Early Jurassic Dunlin Group\r\nand Statfjord Formation. The Triassic comprised the Late Triassic upper Lunde Formation.\r\nThe sandstones of the Brent Group, the Etive Formation, were encountered at\r\n2492.5 m (TVD: 2490 m). The Etive Formation proved oil bearing, and the OWC was\r\ncalculated to be at 2505.5 m (TVD: 2503 m). This was a thinner oil column than prognosed\r\nand the resources for the prospect were thus reduced compared to what was\r\nexpected. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe sandstones of the Statfjord Formation\r\nproved water bearing.\u003c/p\u003e\r\n\r\n\u003cp\u003eFirst sign of petroleum ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"622","properties":{"OBJECTID":622,"wlbNpdidWellbore":1245,"wlbName":"7224/7-1","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 7224/7-1 was drilled in Lopparyggen\r\nØst area on the Bjarmeland Platform. The hole was drilled on the Samson Dome\r\nstructure with closure on all pre-Oligocene levels. The well was designed to\r\ntest sandstone reservoirs of Early Jurassic/Late Triassic and Early Triassic\r\nages and carbonaceous rocks of Permian age. In addition, the well was to test\r\nthe geophysical and structural interpretation, and improve the geological,\r\ngeochemical and paleontological understanding of a new area in the Barents Sea.\r\n Planned TD was originally at 4400 m, into Permian carbonates. However, as the\r\nresult from well 7226/11-1 about 70 km further east turned out to be negative\r\nregarding the Permian rocks, it was decided to reduce TD to 3200 m. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 7224/7-1 was spudded with\r\nthe semi-submersible rig Ross Rig 13 April 1988 and drilled to TD at 3067 m in\r\nTriassic rocks. During drilling Statoil reported increasing pressure and\r\nrelatively high connection gas readings. At 2352 m gas flowed in from the\r\nformation. During further drilling the pore pressure increased to 1.48 SG in\r\nthe formation at 2621 m, and Statoil decided to stop drilling and set casing at\r\n2658 m. The 9 5/8" casing was set at 2644 m. Further drilling to TD went\r\nwithout significant problems. The well was drilled with seawater and hi-vis\r\npills down to 664 m and with Newdrill polymer / Drispac from 664 m to TD. There\r\nwas no shallow gas in the hole.\u003c/p\u003e\r\n\r\n\u003cp\u003eMiddle Jurassic sandstone (Stø Formation)\r\ncame in at 894 m. Jurassic/Late Triassic reservoir section had good reservoir\r\nquality. In the Triassic section several minor sand zones of Anisian age in the\r\nKobbe formation was penetrated. Bottom Smithian sandstone (Klappmyss),\r\nprognosed at 2730 m, was not encountered as expected. Shows were recorded in\r\nthe Stø, Nordmela and Tubåen formations from 894 m to 931 m, but logs and RFT tests\r\nshowed that the sandstones were water bearing. The petrophysical evaluation\r\nindicate","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"623","properties":{"OBJECTID":623,"wlbNpdidWellbore":1246,"wlbName":"6408/4-1","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eBlock 6408/4 is situated on the eastern\r\nside of the Trøndelag Platform off shore mid Norway. The drilled prospect is a\r\nlarge, gently dipping structure that is bounded by a southeast dipping fault\r\nwith dip closure in all other directions.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe objectives were to test for the\r\ndevelopment of the Late Jurassic Rogn sands and their hydrocarbon potential,\r\nand to test for hydrocarbons in the Middle Jurassic Fangst sands. Both Late\r\nJurassic shales and the Lower Jurassic Åre coal unit were considered to be\r\nimmature on the block. Long distance migration of oil was a critical aspect of\r\nthe prospect and as such constituted a major risk.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 6408/4-1 was spudded with\r\nthe semi-submersible installation Vinni on 18 September 1988 and drilled to TD\r\nat 2725 m in the Triassic Grey Beds. There were certain problems with hole\r\nstability down to 830 m. The drill string twisted off at 370 m and had to be\r\nfished up. During logging the tool did not get past 622 m, and due to this\r\nthere is a lack of conventional log between 622 - 830 m. Otherwise operations\r\nwent without significant problems. The well was drilled with seawater and\r\nhi-vis pills down to 830 m and with KCl/polymer mud from 830 m to TD. No\r\nshallow gas was encountered.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe prognosed sand in the Rogn Formation\r\nwas not developed. A change from high gamma response shale to lower gamma\r\nresponse at 1734 m in the Spekk Formation was noted. The reservoir sections in\r\nthe Middle and Early Jurassic Fangst Group were encountered at 1825 m to2015 m\r\nwith 140 m net sand with 30.5% average porosity (log evaluation). The Båt group\r\nand the Triassic also had sands; the most massive of these was the Tilje\r\nFormation with 130 m net reservoir with 25.6% average porosity. All reservoir\r\nsections were water bearing and there were no shows or stain recorded while\r\ndrilling. One core was cut between 1745 m to 1746.4 m in the Spekk Formation. A\r\nsecond core was attempted with","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"624","properties":{"OBJECTID":624,"wlbNpdidWellbore":1250,"wlbName":"15/5-2 R","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 15/5-2 R is a re-entry of well\r\n15/5-2 in the Ve Sub-basin in the North Sea, north of the Sleipner Vest Field\r\nand 15/5-1 Gina Krog Discovery. Well 15/5-2 found gas in Jurassic and Triassic\r\nsandstones and was suspended without testing. The objective of the re-entry was\r\nto conduct a production test from the Triassic reservoir. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 15/5-2 was re-entered with the\r\nsemi-submersible installation Treasure Seeker on 2 November 1979. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAfter testing, the well was plugged and\r\npermanently abandoned on 7 December 1979. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eTesting\u003c/span\u003e\u003c/b\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eTwo FIT runs at 4150 m were attempted in\r\norder to obtain fluid samples. Both runs failed. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eA production test was run in the Triassic\r\nHegre Group over the perforated intervals 4142 - 4146 and 4148 -4152 m. The\r\ntest produced 304120 Sm3 gas and 17.6 Sm3 liquid hydrocarbons /day through a\r\n48/64” choke. The gas/condensate ratio was 17260 Sm3/Sm3, the condensate\r\ngravity was 49 °API, and the gas gravity was 0.622 (air = 1). The reservoir\r\ntemperature estimated from the test is 130.6 °C (267 °F).\u003c/span\u003e\u003c/p\u003e\r\n\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"625","properties":{"OBJECTID":625,"wlbNpdidWellbore":1278,"wlbName":"34/7-14","wlbHistory":"\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 34/7-14 was drilled in on the\r\n"B-structure", today named the Tordis Field, in the southern part of\r\nblock 34/7. The Middle Jurassic Brent Group reservoir is located in tilted\r\nfault blocks dipping in a westerly direction within the southern fault segment\r\nabout 1.4 km south of the well 34/7-12. The structure has a NE-SW trend and is\r\nbounded to the east and north by major faults, i.e. Northern Main Fault and\r\nSouthern Main Fault with throws of 50-200 m. The primary purpose of well\r\n34/7-14 was to further delineate and appraise the Tordis Field. The main target\r\nof the well was the sandstones in the Brent Group. Secondary objective was the\r\nsandstones of the Early Jurassic Cook Formation.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 34/7-14 was spudded with\r\nthe semi-submersible installation "Vildkat Explorer" on 28 September\r\n1989 and drilled to a total depth of 2653 m in the Early Jurassic Burton\r\nFormation. Shallow seismic indicated gas at 246 & 285 m, 344 m, 376 m, and\r\n511 m. Measurement and logging while-drilling (MWD) verified the indication at\r\n511 m as a thin, gas-filled sand. The upper part of the well was drilled as a 9\r\n1/2" pilot hole without a riser and was plugged back from 511 m due to\r\nlack of reliable gas readings in the sand layer. Lost circulation occurred at\r\n2137 m, and the well was plugged back to the 13 3/8" casing shoe. The well\r\nwas drilled with gel mud (barite, bentonite, caustic soda, soda ash) down to\r\n495 m and with KCl mud from 495 m to TD. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eDown to 2189 m, the top of the Brent\r\nreservoir, the well proved mainly claystones. Exceptions to this were the sandy\r\nUtsira Formation of Miocene/Pliocene age encountered at 856 m, and sandstones\r\nwithin the Hordaland Group encountered in the interva","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"626","properties":{"OBJECTID":626,"wlbNpdidWellbore":1279,"wlbName":"25/1-7 R2","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 25/1-7 was drilled on the main Frigg\r\nstructure close to the UK border. The Frigg Field was discovered by well 25/1-1\r\nin 1971. Production from the field started in 1977. A main objective of well\r\n25/1-7 was to establish a reference monitoring station for the production of\r\ngas from the Frigg Field. The objective of the re-entry 25/1-7 R2 was to record\r\nthe fluid contacts. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eSemi-submersible installation West\r\nVanguard arrived the 25/1-7 location on 3 May 1988. Three days were spent on\r\nrepairing damage on the ROV and clearing off fishing net that was entangled in\r\na rail nearby the well head. Appraisal well 25/1-7 R2 was connected and\r\nre-entered on 7 May 1988.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was logged (2050 - 1910 m) through\r\ncasing with a Thermal Neutron Decay (TDT) log to determine the fluid contacts. The\r\ncontacts found were: base of gas at 1925.4 m MSL, and top of highest water at 1930.2\r\nMSL. No oil leg was observed. From this it was concluded: 1) the gas liquid\r\ncontact has risen 1.8-3.6 m since 14 February 1987, and 22.6 m since pre-production\r\nlevel (1948.0 m MSL reference). This, compared with 11 m rise in the period 19\r\nApril 1985 to 14 February 1987, shows that the water rise is temporarily\r\nblocked by shale barriers; 2) The vertical sweep efficiency by water is 100%,\r\nwhich means that all gas-filled sands behind the front are swept.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was suspended on 10 May 1988 as\r\na gas appraisal well. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eTesting\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo drill stem test was performed.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"627","properties":{"OBJECTID":627,"wlbNpdidWellbore":1284,"wlbName":"7321/7-1","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 7321/7-1 was the first well drilled\r\non the license. It is located in the Fingerdjupet Sub-basin in the Bjørnøya Øst\r\narea. The primary objective of the well was Jurassic to Triassic sandstones in\r\na rotated fault block. Potential was expected throughout the Middle Jurassic to\r\nBase Carnian interval.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 7321/7-1 was spudded with\r\nthe semi-submersible installation Ross Rig 26 June 1988 at a depth of 3550 m in\r\nEarly Triassic rocks. The hole was drilled to 526 m and then abandoned due to\r\nbuilding up of the angle. The rig was moved 13 m and the well was re-spudded 27\r\nJune 1988. The hole was drilled to setting depth for 20" casing without\r\nreturns to the surface. During drilling of 17 1/2" hole section, problems\r\nwith loss of drilling mud to believed weak/fractured formation occurred. This\r\nlead to setting of 13 3/8" casing shoe at 1430 m, 770 m higher than\r\nplanned. The problem with loss of mud continued below 13 3/8" casing shoe\r\nand down to 1813 m where the loss was considerably reduced. During drilling of\r\nthe Jurassic and Triassic sequences no drilling mud was lost to the formation.\r\nExcept from two fishing operations no significant drilling problems were\r\nexperienced. The well was drilled with seawater and hi-vis pills down to 982 m\r\nand with gelled seawater / polymer from 982 m to TD. There was no shallow gas\r\nin the hole. \u003c/p\u003e\r\n\r\n\u003cp\u003eTop reservoir (Stø Formation) was\r\nencountered at 1998.5 m, 97.5 m deeper than prognosed. An Intra Carnian\r\nreflector prognosed at 2736 m and was encountered at 2751 m, only 15 m deeper\r\nthan prognosed. Near bottom a Carnian seismic reflector was encountered at 3448\r\nm. The mud log and wire line logs indicated good reservoir parameters for a gas\r\nsand in the interval 2384.8 m to 2390.4 m in the Snadd Formation. Log analysis\r\nshowed good porosity and low water saturation, 21.2% and 31.1% respectively.\r\nCore analysis indicated clean sand with high porosity. Core perme","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"628","properties":{"OBJECTID":628,"wlbNpdidWellbore":1286,"wlbName":"25/1-8 SR2","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe Frigg Field was discovered by well\r\n25/1-1 in 1971 and set in production in May 1977. Well 25/1-8 S was drilled in\r\nthe summer of 1985 to monitor changes in gas/fluid contact, uncover\r\npermeability barriers and pressure gradients in the Frigg Formation, refine the\r\ngeological model, and provide ties for seismic interpretations. Before\r\nproduction started the Frigg Field fluid contacts were: OWC = 1955.9 m TVD MSL\r\nand GOC = 1948.2 m TVD MSL. In July 1985 in 25/1-8 S found the oil-leg to be\r\nall swept with the exception of a very thin oil-layer lifted to 1903.5 m TVD\r\nMSL, 2 m below the new gas/liquid contact, which was now a gas/water contact\r\n(GWC) at 1901.3 m TVD MSL. The objective of the re-entry well 25/1-8 SR was to\r\nmonitor further changes in the GWC.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 25/1-8 S was re-entered\r\n(25/1-8 SR) with the semi-submersible installation Nortrym on 14 February 1987.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe GWC was found at 1898.3 m TVD MSL,\r\nonly 3.2 m higher than in July 1985. The slow water rise was attributed to a\r\nthin shale layer that acted as a barrier for effective drainage.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo cores were cut and no wire line fluid\r\nsamples were taken.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was suspended on 18 February\r\n1987 for later re-entry and monitoring of the reservoir parameters. It is\r\nclassified as a gas appraisal well.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eTesting\u003c/span\u003e\u003c/b\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo drill stem test was performed.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"629","properties":{"OBJECTID":629,"wlbNpdidWellbore":1287,"wlbName":"7/12-7","wlbHistory":"\r\n\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 7/12-7 was drilled on the South East\r\nflank of the Ula Field. The objective was to identify an optimal location and\r\ndepth for a planned water-injection well by appraising the oil/water contact in\r\nthis area.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 7/12-7 was spudded with\r\nthe semi-submersible installation Vildkat Explorer on 20 June 1989 and drilled\r\nto TD at 3855 (3847 m TVD) m in the Late Jurassic Ula Formation. Drilling\r\nproceeded without any significant problems. The well was drilled with seawater\r\nand bentonite down to 174 m, with seawater/bentonite/spercell/CMC EHV mud from\r\n174 to 1008 m, and with oil based Safemul mud from 1008 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eTop reservoir was encountered at 3772 m\r\n(3765.5 m TVD) and the reservoir was oil bearing. Cores had oil shows down to\r\nthe base of the last core at 3842 m. A well defined OWC or free water level was\r\nnot found, though water saturations were seen to rise to the range 60-90% at ca\r\n3819 m. Core porosity and permeability, RFT tests, and geochemical analysis\r\nshowed a division between producible and residual oil to at 3815 m. From this\r\nit was concluded that that the lower contact for producible oil at the Ula East\r\nwas ca 290 m deeper than at Ula West. Pressure measurements proved\r\ncommunication with the pressure-depleted parts of the Ula Field.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eFour cores were cut in the well in the\r\nUla Formation in the interval 3800 to 3842.2 m. Core depths are ca 2 m deeper\r\nthan loggers' depth. Segregated fluid samples were taken at 3797 m, 3834 m and\r\n3842 m. The 2 3/4 gallon chambers from 3834 and 3842 m and the PVT 1 gallon\r\nchamber from 3834 m were drained at surface and contained water with\r\nindications of oil. On-shore geochemical analysis of the PVT 1 gall","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"630","properties":{"OBJECTID":630,"wlbNpdidWellbore":1288,"wlbName":"35/8-3","wlbHistory":"\r\n\r\n\r\n\r\n\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 35/8-3 was drilled in the southern\r\nend of the Sogn Graben in the Northern North Sea. The primary objective was to\r\nassess the hydrocarbon potential of the Brent Group sandstones, which flowed\r\ngas-condensate in wells 35/8-1 and 35/8-2. The Brent Group was expected to be\r\n212 m thick and to be encountered at a depth of 3631 m subsea. Secondary\r\nobjectives were Late Jurassic Intra-Heather Formation sandstones, and possible\r\nIntra-Early Cretaceous sandstones.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 35/8-3 was spudded with the\r\nsemi-submersible installation Treasure Scout on 6 July 1988 and drilled to TD\r\nat 3944 m (3947 m logger's depth) in the Middle Jurassic Brent Group. No\r\nshallow gas was observed. While drilling the 12 1/4" section the drill\r\nstring got stuck in Heather sands at 3539 m. After 7 days unsuccessful fishing\r\nthe hole was plugged back to 3308 m. It was sidetracked from 3371 m and drilled\r\nto section TD at 3560 m. The BHA got stuck a second time at 3863 m in the 8\r\n1/2" section. After 5 days with several fishing attempts by jarring the\r\nBHA was fished after spotting a diesel based fluid. The diesel was circulated\r\nout and the well was drilled to its final TD. The well was drilled with spud\r\nmud down to 830 m, with Drispac and seawater from 830 m to 2174 m, and with\r\nKCl/polymer mud from 2174 m to TD. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eHydrocarbon indications while drilling\r\nwere minor except in the Late Jurassic Heather sands.\u003c/span\u003e\u003cspan\r\nlang=EN-GB\u003eLog analyses of the Heather sands indicated a probable gross gas\r\ncolumn of 70 m with a net pay of 31.9 m. Average porosity in the net sand was\r\n15.6% with an estimated average water saturation of 22%. An RFT pressure-depth\r\nplot confirmed a gas column with an estimated 0.162 psi/ft (3.66 KPa/m)\r\npres","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"631","properties":{"OBJECTID":631,"wlbNpdidWellbore":1290,"wlbName":"25/2-12","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 25/2-12 was the\r\nsecond hole drilled on an NNESSV-oriented structural height in the northwestern\r\npart of the block. Well 25/2-4, which was drilled in 1975 in a more down flank\r\nposition, found a 21 m gas column and a 48 m oil column in the Vestland Group.\r\nThe Statfjord Formation was water bearing in 25/2-4, but its position was not\r\noptimal on the structure with regards to the Jurassic prospects.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe main objective\r\nof well 25/2-12 was to examine the Statfjord Formation higher up on the\r\nstructure than 25/4-2, including getting more information about the oil and gas\r\ndiscovery in the Vestland Group.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eAppraisal well\r\n25/2-12 was spudded 17 July 1988 by Smedvig semi-submersible rig West Vanguard\r\nand completed 13 November 1988 at a depth of 4103 m in the Late Jurassic\r\nStatfjord Formation. A 17 1/2" pilot hole was drilled from 197- 907 m and\r\nthen opened to 26". Sand layers were encountered at 214 m and 259 m RKB,\r\nand MWD measurements showed no indication of shallow gas. Drilling proceeded\r\nwithout any significant problems down to 1366 m where metamorphic gravel\r\nplugged the bit so that it had to be changed. During clean-up of the hole, mud\r\nwas lost to the sand formation at 890 m to 1000 m. "Lost circulation\r\nmaterial" (LCM) was pumped into the well to isolate it. The well was in\r\nperiods unstable.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe Frigg Formation\r\nwas water bearing. The gas readings were at times very high (up to 80 %). There\r\nwas danger of losing the mud in Turonian limestone. Some fractures were\r\nobserved higher up in the section. There were traces of gas in the limestone.\r\nTop Vestland Group came in at 3685.5 m, 112 m deeper than prognosed. The reason\r\nfor this was assumed to be that the top of the Vestland Group had been faulted.\r\nThe fluid contact was set to 3701 m. Analysis of this showed that it was a\r\ncondensate column of 15 m. A total of five cores were cut. Core 1 was a\r\n"junk core". Cores 2 & 3 ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"632","properties":{"OBJECTID":632,"wlbNpdidWellbore":1294,"wlbName":"9/2-3","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 9/2-3 is located ca 11.5 km\r\nsouthwest of the Yme Field in the Egersund Basin. The objectives of the well\r\nwere to test the sandstones of Late/Middle Jurassic age, the Sandnes- and Bryne\r\nformations. Furthermore the 9/2-3 well will test the geophysical and structural\r\ninterpretation of the area and improve the paleontological, geological and\r\ngeochemical understanding of this area in the North Sea. A strong reflector was\r\nobserved at 253 m, but was expected to be a change in lithology rather than\r\nshallow gas.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 9/2-3 was spudded with the\r\nsemi-submersible installation Vildkat Explorer 4 December 1989 on and drilled\r\nto TD at 3424 m in the Middle Jurassic Bryne Formation. No shallow gas was\r\nencountered in this well. Drilling went on without significant difficulties.\r\nThe well was drilled with seawater/gel/bentonite down to 376 m, with\r\ngypsum/polymer mud from 376 m to 3210, and with a polymer/Resinex mud from 3210\r\nm to TD. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe Sandnes Formation was encountered at\r\n3252 m and proved oil. The OWC was difficult to place from the logs, but was\r\nestimated at 3273 m. This gives a 21 m oil column. Gross reservoir interval was\r\nfound to be 115 m. Core and log analysis indicate a fairly low porosity\r\nsandstone with small amounts of silt, shale and limestone (calcite cement). The\r\nBryne Formation proved to be water bearing, and no test was performed in this\r\nformation. \u003c/p\u003e\r\n\r\n\u003cp\u003eOrganic geochemical analyses show that\r\nthe Tau Formation (3098 m to 3188 m) is an excellent source rock with TOC in\r\nthe range 3 to 13 % and hydrogen index in the range 360 to 700 mg HC/g TOC. The\r\nTau Formation is early oil-window mature (%Ro around 0.6 and Tmax from 430 to\r\n435 deg C) in the well. Analyses of the DST oil show a somewhat higher maturity\r\nthan the in-well source rock. Furthermore, the oil showed a close resemblance\r\nto the 9/2-1 DST 3 oil. \u003c/p\u003e\r\n\r\n\u003cp\u003eOne conventional core was cut in the\r\nSandnes formation in the interval 326","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"633","properties":{"OBJECTID":633,"wlbNpdidWellbore":1302,"wlbName":"34/10-33","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 34/10-33 was the sixth well drilled\r\nto reservoir level on the Gullfaks South structure. The main objective of the\r\nwell was to appraise the oil and gas reserves in the Brent Group on the\r\nnorthern part of the structure. The gas/oil and oil/water contacts were to be\r\nconfirmed at 3324 m and 3395 m MSL respectively. Secondary objective was to\r\npenetrate 50 m of the Statfjord Formation to obtain data to better understand\r\nthe structural development in the area, and also update the geological model\r\nfor the upper part of the formation. A positive result would lead to the\r\ndrilling of a horizontal testing well as a sidetrack from this well.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell was spudded with the\r\nsemi-submersible installation West Delta on 25 September 1988 and drilled to TD\r\nat 3870 m in the Early Jurassic Statfjord Formation. There was some shallow gas\r\nat 477 - 478 m. Due to this the 20" casing was set at 450 m. There was a\r\nproblem with a leakage in the BOP. The drill string got stuck when setting the\r\n13 3/8" casing and the MWD and drill bit had to be changed. The well was\r\nclose to vertical down to ca 2500 m. From there the well built inclination\r\ngradually up to 20 deg at TD. At TD true vertical depth is estimated to be ca\r\n20 m less than measured depth. The well was drilled with spud mud down to 483\r\nm, with gypsum/polymer mud from 483 m to 3161 m, and with\r\ngel/lignosulphonate/lignite mud from 3161 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eTop Brent Group, Tarbert Formation came\r\nin at 3186 m with gas and oil. FMT data showed a gas/oil contact at 3268 m, 85\r\nm higher than prognosed. Approximately 150 m of oil was found vertically down\r\nto top Dunlin Group at 3424 m, much more than expected. No oil/water contact\r\nwas seen. There was a pressure shift of 1.5 - 2 bar at","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"634","properties":{"OBJECTID":634,"wlbNpdidWellbore":1306,"wlbName":"30/9-7","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 30/9-7 was drilled on the B-prospect\r\nin the Oseberg South area. The prospect is an easterly tilted fault block,\r\nseparated from the Omega structure by a NNW-SSE trending normal fault. The\r\nobjective was to prove oil in the Brent Group sandstones and define an\r\noil/water contact. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 30/9-7 was spudded with the\r\nsemi-submersible installation Polar Pioneer on 2 November 1988 and drilled to\r\nTD at 3565 m in the Early Jurassic Nansen Formation. No significant problem was\r\nencountered in the operations. The well was drilled with spud mud down to 1072\r\nm and KCl/polymer mud from 1072 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 30/9-7 encountered oil in the Brent\r\nGroup, Tarbert Formation. No additional hydrocarbon bearing intervals were found.\r\nThe Tarbert Formation (2810 - 2903 m) was oil bearing down to 2827 m (OWC from\r\nRFT). The net pay was estimated to be 13.6 m and average water saturation\r\ncalculated to 37.9%. Average porosity was 21.2%. RFT results showed no pressure\r\ncommunication with well 30/9-4 in the Omega structure within the Tarbert\r\nFormation. Some oil shows were described in thin sandstone stringers at the\r\nbase of the Våle Formation and down into limestones in the uppermost Shetland\r\nGroup (2375 m to 2382 m). Below OWC in the Tarbert Formation, sandstones had no\r\nto weak petroleum odour and cut fluorescence down to 2880 m and brown dead oil\r\nstain and weak cut fluorescence down to 2885 m.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eTwo cores were cut in the Tarbert\r\nFormation from 2832 m to 2888 m. RFT fluid samples were taken at 2818.2 m (oil,\r\nwater and filtrate) and at 2828.6 m (water and filtrate). \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was suspended on 23 December\r\n1988. It was permanently ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"635","properties":{"OBJECTID":635,"wlbNpdidWellbore":1308,"wlbName":"2/5-8","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 2/5-8 is located on the South East\r\nTor Field in block 2/5 in the Central Trough in the North Sea. The overall\r\noutline of the field had previously been defined by the wells 2/5-3 and 2/5-5. The\r\npurpose of the well was to test the distribution of high-porosity, re-deposited\r\nchalk and productive zones west of the major NS trending crestal fault in the\r\nfield. It was also planned to test the productivity of the chalk in both the\r\nEkofisk and the Tor Formations on the flanks, confirm reserve calculations for\r\nthe structure and get good oriented core coverage in both formations.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eAppraisal well 2/5-8 was spudded with the\r\nsemi-submersible installation Dyvi Stena on 18 September 1988 and drilled to TD\r\nat 3367 m in the Late Cretaceous Hod Formation. Drilling proceeded without\r\nsignificant problems. The well was drilled with seawater and pre-hydrated gel\r\nsweeps down to 370 m and with water based gypsum/polymer non-dispersed mud from\r\n370 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eTop Ekofisk came in at 3107 m and top Tor\r\nFormation at 3204 m. Two cores were cut in the interval 3115 - 3142.5 m in the\r\nEkofisk Formation and another three cores in the interval 3207 - 3291 m in the\r\nTor Formation. The chalk was of a relatively poor reservoir quality both in the\r\nEkofisk and Tor Formation, and oil staining were only found along fracture\r\nplanes in cores from the Tor Formation. The logs confirmed the negative result\r\nfrom the cores. \u003c/p\u003e\r\n\r\n\u003cp\u003eNo fluid samples were taken in the well.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 5 November 1988 as a dry well with shows.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was performed.\u003c/p\u003e\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"636","properties":{"OBJECTID":636,"wlbNpdidWellbore":1309,"wlbName":"6507/8-3","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 6507/8-3 was the third in the block,\r\nlocated on the Sør High northeast of the Heidrun Field. The hole was drilled on\r\nthe alpha-structure, a rotated fault block dipping towards south and west.\r\nJurassic and parts of Triassic is probably eroded. The primary objective of the\r\nwell was to test the hydrocarbon bearing potential of the previously undrilled\r\nalpha structure. The secondary objective was to verify geological model and\r\nstructural interpretation, to drill the third commitment well in the block, to\r\nimprove the paleontological, geological and geochemical understanding of the\r\narea. Planned TD was in Triassic sediments.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 6507/8-3 was spudded with\r\nSmedvig Drilling semi-submersible installation West Delta on 3 September 1988\r\nand drilled to TD at 2075 m in Triassic rocks of the Åre Formation. The well\r\nwas drilled with spud mud down to 558 m, with CMC from 558 m to 1101 m, and\r\nwith gel/CMC/Ligno from 1101 m to TD. There was no shallow gas. The whole\r\noperation went very fast and without problems of any kind and TD was reached in\r\n11 days. \u003c/p\u003e\r\n\r\n\u003cp\u003eBoth the Eocene to Miocene and the\r\nCretaceous are missing in the well. Top reservoir (Garn Formation) was\r\nencountered at 1358 m. It contained a small amount of gas with a gas/water\r\ncontact at 1362 m. FMT testing at 1361 m showed dry gas consisting of 99%\r\nmethane, interpreted to be of biogenic origin. Apart from this methane the well\r\nwas found to be dry based on cuttings, cores, and logs. Two cores were cut in\r\nthe well. Core 1 was cut between 1367 ? 1380 m (only the lower 1.5 m from the\r\nNot Formation recovered) and core 2 in the interval 1396 -1408 m in the Ile/Ror\r\nFormations.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was plugged and abandoned\r\ncompleted 20 September 1988 at as dry.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was performed\u003c/p\u003e\r\n\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"637","properties":{"OBJECTID":637,"wlbNpdidWellbore":1311,"wlbName":"7/12-8","wlbHistory":"\r\n\r\n\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 7/12-8 was drilled on the south\r\neastern flank of the Ula Field in the North Sea. The well was drilled to\r\nevaluate the reservoir potential of the south eastern sector of the Field and\r\nto assist target future water injection wells. To enable a full evaluation of\r\nthe reservoir the lower Ula Formation and the underlying Triassic section were\r\npenetrated.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 7/12-8 was spudded with\r\nthe semi-submersible installation Vildkat Explorer on 3 October 1988 and\r\ndrilled to TD at 3900 m in the Triassic Skagerrak Formation. Drilling down to\r\ntop reservoir proceeded without any significant problems.\u003c/span\u003e\u003cspan\r\nlang=EN-GB\u003e \u003c/span\u003e\u003cspan lang=EN-US\u003eThe well was drilled with seawater and\r\nbentonite down to 167 m, with seawater/bentonite/spercell/CMC EHV mud from 167\r\nto 955 m, with KCl/polymer mud from 955 m to 3721 m, and with oil based Safemul\r\nmud from 3721 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eTop Mandal Formation was encountered at\r\n3640 m, top Farsund Formation at 3663 m, and top Ula Formation at 3718 m, 78 m\r\nhigher than prognosed. RFT measurements showed a pressure barrier at ca 3770 m.\r\nThere was oil down to the barrier and water below. An effective oil/water\r\ncontact was difficult to identify. The saturation profile across interval 3770\r\n- 3796 is interpreted as water influx from the aquifer following production\r\nfrom the field since 1986. The RFT results supported that the Ula reservoir at\r\nthe 7/12-8 location was depleted and in pressure communication with the crestal\r\nproducing part of the Ula Field. There were no signs of hydrocarbons in the underlying\r\nTriassic.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eOne core was cut in the Ula Formation\r\nfrom 3724.0 to 3750.5 m. Segregated RFT fluid samples were taken at 3772 m\r\n(wa","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"638","properties":{"OBJECTID":638,"wlbNpdidWellbore":1313,"wlbName":"2/4-13","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 2/4-13 was drilled in the\r\nmiddle of a northwest to southeast trending structural/stratigraphic closure on\r\na rotated fault block, about 12 km north of the Ekofisk Field in the North Sea.\r\nThe primary purpose of the well was to assess the hydrocarbon potential and to\r\ntest the reservoir potential of Late Jurassic sandstone. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 2/4-13 was spudded with the\r\nsemi-submersible installation Treasure Saga on 3 September 1988.\u00A0 The well was\r\ndrilled through the 36", 26", and 17 1/2" sections. The 17 1/2\r\nsection was logged before the 13 3/8 casing was run and cemented with shoe at\r\n2503 m. Problems with the seal assembly occurred, which eventually lead to\r\nplugging and abandonment of the well. The well was drilled with spud mud and\r\ngel down to 921 m and with KCl mud from 921 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well penetrated the Nordland Group to\r\na total depth of 2518 m, 847 m into the Hordaland Group. Shallow gas was seen\r\non MWD between 560 m and 650 m. Below this level background gas varied between\r\n1 - 15 % with trip gas up to 32%. The gas was composed of C1 and C2 with trace\r\nC3 towards TD. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 6\r\nOctober 1988 as a junked well. The rig was moved 53.4 m NNW for spudding of a\r\nnew well bore with the same objectives, well 2/4-14.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was performed.\u003c/p\u003e\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"639","properties":{"OBJECTID":639,"wlbNpdidWellbore":1338,"wlbName":"34/8-3 A","wlbHistory":"\r\n\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 34/8-3 A is a sidetrack to well\r\n34/8-3 on the A-structure on the Visund Field. Well 34/8-3 found oil and gas in\r\nthe Brent Group without encountering the OWC. Well 34/8-3 A was sidetracked\r\ndown flanks on the structure to establish the OWC and to test if the A-North\r\ncould be in communication with the 34/8-1 A-South Discovery.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 34/8-3 A was kicked off at\r\n944 m in the primary well on 14 November 1988. It was drilled with the\r\nsemi-submersible installation Polar Pioneer to TD at 3230 m (3091 m TVD) in the\r\nEarly Jurassic Cook Formation. During logging before setting of 9 5/8",\r\nthe tool got stuck at 1284 m. The string was cut, and the instrument was fished.\r\nThe well was drilled with KCl/polymer mud from kick-off to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eSpotted hydrocarbon shows were described\r\non cuttings in the interval 2550 to 2660 m in the Kyrre Formation. Top Draupne\r\nFormation was encountered at 3003 m. Under Draupne, the sidetrack penetrated a\r\n19 m thick Heather Formation sequence that was not present in the primary well\r\nbore. The Brent Group, Tarbert Formation was encountered at 3031 m (2900 m TVD),\r\ndeeper than prognosed due to the unexpected Heather. The Brent Formation\r\ncontained gas down to a gas/oil contact at 3059 m (2927 m TVD and oil down to a\r\nclear oil/water contact at 3099.5 m (2966 m TVD). Oil shows continued down to\r\n3162 m. The Cook Formation was found water bearing. The RFT pressures in both the\r\nprimary well and the sidetrack proved higher pressure in the hydrocarbon zone\r\nthan on the A-South compartment, but with pressure communication in the water\r\nzone.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eFive cores were cut in the interval 3034\r\nto 3148.5 m. The drill string got stuck during cutting of ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"640","properties":{"OBJECTID":640,"wlbNpdidWellbore":1339,"wlbName":"7321/9-1","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 7321/9-1 was drilled on a rotated\r\nfault block on the southern margin of the Fingerdjupet Sub-basin in the\r\nBjørnøya East area. The main objective was to test the hydrocarbon potential of\r\nthe structure, with Late Triassic to Middle Jurassic sandstones as primary\r\ntarget horizon with Early Cretaceous and Triassic (Snadd Formation) sandstones\r\nas secondary targets. The wildcat well should also gather as much geological\r\ninformation as possible regarding reservoir, source and cap rock intervals. The\r\nwell was positioned so that it should avoid faults that could disturb the\r\nseismic tie and at the same time would leave a minimum of untested potential\r\nup-dip from the well location.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 7321/9-1 was spudded with\r\nthe semi-submersible rig Ross Rig 25 October 1988 and drilled to TD at 1800 m\r\nin the Late Triassic Snadd Formation. Drilling proceeded to TD without any\r\nsignificant problems, but on the way out of the hole the string got stuck at\r\n1501 m. After several unsuccessful attempts, the string was shot off at 1377 m.\r\nAs a result of this, and because LWD logs were run only to 1507 m (Baroid\r\n"Recorded Lithology Logging" -tool, RLL), the hole below 1507 m was\r\nnot logged. There were also mechanical problems during plugging. In total as\r\nmuch as 40% of the rig time was thus classified as down time. The well was\r\ndrilled with seawater and hi-vis sweeps down to 680 m and with KCl / polymer\r\nmud from 680 m to TD. There was no shallow gas in the hole. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe secondary target, a prognosed\r\nsandstone above the Barremian unconformity, was not developed. Instead of a\r\nreservoir sandstone a new possible source rock with high organic content was\r\nencountered in the Barremian interval from 961 m to 986 m. The primary target\r\nreservoir interval (Stø, Nordmela and Fruholmen Formations) was penetrated at\r\n1378.8 m. Approx. 116 m of reservoir rock was found with 35.8 m net sand. The\r\nreservoirs were water bearing with ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"641","properties":{"OBJECTID":641,"wlbNpdidWellbore":1340,"wlbName":"6507/8-4","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 6507/8-4 was designed to drill the\r\nHeidrun North Structure, a horst block northeast of the Heidrun Field situated\r\nin the transition zone between the Nordland Ridge to the north and the Halten\r\nTerrace to the southwest. The primary objective of the well was to test\r\nsandstones of Early Jurassic age. The well would also test the geophysical and\r\nstructural interpretation and improve the paleontological, geological and\r\ngeochemical understanding of the area.\u003c/p\u003e\r\n\r\n\u003cp\u003eShallow gas warning was given at 608 m,\r\n745 m and 686 m, the last one classified as a medium/ high risk anomaly. Problems\r\nwith gumbo clay and sloughing shale had been experienced in the Eocene /\r\nPaleocene sections in the Haltenbanken area.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 6507/8-4 was spudded with\r\nthe semi-submersible installation Deepsea Bergen on 14 June 1990 and drilled to TD at 2560 m in the Triassic Grey Beds. Apart from some tight hole spots,\r\ndrilling proceeded without significant problems. The well was drilled with\r\nseawater and hi-vis sweeps down to 654 m, with seawater and CMC EHV mud from\r\n654 m to 1555 m, with gypsum/polymer mud from 1555 m to 2100 m, and with\r\ngel/ligno mud from 2100 m to TD. Shallow gas was encountered at 596 m and at 686\r\nm. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe only shows reported above the target\r\nreservoir were on claystones at 2102 m and at 2104 m. Top reservoir (Åre\r\nFormation) was encountered directly underlying Late Cretaceous sediments at\r\n2124 m. The hiatus was from the Early Jurassic, Sinemurian to the Late\r\nCretaceous, Santonian. The well proved gas and oil in the Åre formation. The\r\nGOC was set at 2142 m and the OWC at 2251.5 m. Shows continued down to 2290 m.\u003c/p\u003e\r\n\r\n\u003cp\u003eA total of 170.25 m core was recovered in\r\neleven cores, all from the Åre Formation in the interval 2128 to 2318 m. Twenty-five\r\nsidewall cores were attempted and 22 were recovered. An FMT fluid sample was\r\ntaken at 2158.5 m. It contained only 500 cc mud filtrate due to plugging. Another\r\nsample wa","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"642","properties":{"OBJECTID":642,"wlbNpdidWellbore":1342,"wlbName":"6506/12-6","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 6506/12-6 was the third on the Alpha\r\nstructure in block 6506/12, and the first appraisal well on this structure.\u003c/p\u003e\r\n\r\n\u003cp\u003e6506/12-1 was a gas/condensate discovery\r\nwell on the Alpha South segment while 6406/12-4 encountered only traces of\r\nhydrocarbons on the high-pressured Alpha North segment. 6506/12-6 was\r\nclassified as an appraisal well, and designed to further examine the\r\nhydrocarbon potential, of the Alpha South segment. The primary objectives were\r\nto verify the structural interpretation of the segment, and to define\r\nhydrocarbon-water contacts.\u003c/p\u003e\r\n\r\n\u003cp\u003ePrimary targets were the Fangst and BÅt\r\nGroup sandstones and the upper Cromer Knoll Group sandstone unit (Lysing\r\nFormation). Prognosed depth was 4780 m.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eAppraisal well 6506/12-6 was spudded with\r\nthe semi-submersible installation Dyvi Delta on 31 March 1986 and drilled to TD\r\nat 4741 m, 6 m into Early Jurassic sediments of the Åre Formation. The 26"\r\nsection was drilled first as a 12 1/4" pilot hole and then opened up with a\r\n26" underreamer. At 777 m a survey indicated that the 26" hole was\r\ndeviated from the pilot hole. After pulling out of hole and successfully\r\nreaming into the old pilot, the hole was opened up first to 17 1/2" bit,\r\nand then to 26". This was drilled to 1078 m before it was realised that\r\nthe bit had again entered the deviated hole. After reaming suspected kick-off\r\npoint drilling finally commenced in the vertical path to casing point. No\r\nfurther significant drilling problems occurred. The well was drilled with\r\nseawater down to 414m, with gypsum/polymer mud from 414 m to 1056 m, and with\r\ngypsum/polymer/lignite mud from 1056 m to TD\u003c/p\u003e\r\n\r\n\u003cp\u003eThe Lysing Formation sandstone was\r\npenetrated from 3248 m to 3271 m. Well samples from this interval had weak\r\nshows (fluorescence but no cut). Top Shetland Group came in at 2331 m, top\r\nCromer Knoll Group at 3274 m, and top Spekk Formation 4021 m. Top reservoir was\r\nencountere","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"643","properties":{"OBJECTID":643,"wlbNpdidWellbore":1343,"wlbName":"2/4-14","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 2/4-14 was designed to drill the\r\nsame structure on the Steinbit Terrace as well 2/4-13, which was junked on 6\r\nOctober 1988 due to technical problems. The wells were drilled in the middle of\r\na structural/stratigraphic closure on a rotated fault block. Their primary\r\nobjectives were to assess the hydrocarbon potential of the main structure in\r\nblock 2/4. The target was expected Late Jurassic sandstone.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 2/4-14 was spudded with the\r\nsemi-submersible installation Treasure Saga on 6 October 1988, 53.4 m NNW of\r\nthe 2/4-13 location. It was drilled to TD at 4734 m in the Late Jurassic Tyne\r\nGroup. The well was drilled with spud mud and gel down to 916 m, with KCl mud\r\nfrom 916 m to 4453 m, and with Hi Temp Polymer mud from 4453 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eDrilling went without significant\r\nproblems down to 3687 m in the 12 1/4" section. On trip out of hole the\r\ndrill string got stuck with the bit at 3538 m. The pipe could not be freed and\r\na cement plug was set from 3475 m to 3395 m. A technical sidetrack was kicked\r\noff from 3415 m to 3463 m. Due to high temperatures the MWD worked only in\r\npart, but drilling of the remaining part of the 12 1/4" section to 4453 m\r\nproceeded without significant problems. The 8 1/2" hole was drilled to\r\n4713 m where gas cut mud were observed with a maximum gas reading of 68 %. The\r\nhole was drilled to 4714 m when the mud weight was increased to 2.10 SG. This\r\nmud weight was near the fracture gradient at the casing seat. The equivalent\r\ncirculating density at the drilling pump rates exceeded the fracture gradient\r\nat the casing seat. At 4734 m the well kicked, and gained a total 6.5 m3. The\r\nwell was shut in and several attempts were made to gain control, without\r\nsuccess. Coil tubing was run in to 4691 m and drill pipe circulated to\r\nseawater. A 1/2 bbl was taken and the well closed in. Finally, as the drill\r\npipe started to come out of the hole, the shear-rams were activated and the","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"644","properties":{"OBJECTID":644,"wlbNpdidWellbore":1346,"wlbName":"25/5-2","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 25/5-2 was\r\ndesigned to drill the Frøy structure, which is a NNE-SSW tilted Jurassic fault\r\nblock located in the northeastern corner of block 25/5. The main objectives of\r\nthe well were to prove the Southward continuity and extension of the Middle\r\nJurassic reservoir, to determine the OWC in the Frøy Field, to test the\r\nproductivity in the oil zone, and to test the injectivity in the water zone.\r\nThe northern extension of the Frøy structure was drilled in 1977 by well 25/2-6\r\nin a down dip position and proved limited oil shows in the Statfjord Formation.\r\nWells 25/5-1 and 25/5-1 A were drilled in 1987 in the central part of the\r\nstructure, and found oil in the Vestland Group sandstones.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 25/5-2\r\nwas spudded with the semi-submersible rig West Vanguard on 18 April 1989 and\r\ncompleted 4 July 1989 at a depth of 3304 m in the Early Jurassic Drake\r\nFormation. Drilling went without problems to 2300 m where the bit became stuck\r\nafter a wiper trip, and the string was backed of at 2231 m. A technical\r\nsidetrack was started from 2103 m. The string entered into the old hole, and a\r\nsecond sidetrack was started from 2070 m. Below the 9 5/8" casing at 3066\r\nm BSX mud, based on seawater with added NACl and polymers, was used. The MWD measurements\r\nshowed no indication of shallow gas. The Vestland Group, Hugin Formation,\r\ncame in at 3186 m, 67 m deeper than expected. Hydrocarbons were encountered at\r\nthe top reservoir with the oil water contact at 3198 m (3176 m TVD MSL), which is\r\n50 m deeper than the estimated OWC in well 25/5-1 A. Still, RFT Pressure\r\nmeasurements in the oil column indicate pressure communication with the oil\r\ncolumn in well 25/5-1. A total of 4 cores were cut down to 3226 m. The well was\r\nplugged and abandoned as an oil appraisal well.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eTwo drill stem tests\r\nwhere performed. Test 1 was a production and injection test in the Middle\r\nVestland Group water zone from 3222 m to 322","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"645","properties":{"OBJECTID":645,"wlbNpdidWellbore":1350,"wlbName":"7125/1-1","wlbHistory":"\r\n\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 7125/1-1 was drilled in the\r\nLopparyggen East area on the southern end of the Bjarmeland Platform towards\r\nthe Nyslepp Fault Complex. The primary purpose of the well was to test for\r\nhydrocarbons in the Late Triassic/Early Jurassic sandstones of the Kapp Toscana\r\nGroup. These were found hydrocarbon bearing in well 7124/3-1. A secondary\r\nobjective was to test for hydrocarbons in the underlying Middle Triassic Kobbe\r\nFormation. In well 7124/3-1 weak oil shows were seen in sands from this\r\nformation. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 7125/1-1 was spudded with\r\nthe semi-submersible installation Ross Rig 30 November 1988 and drilled to TD\r\nat 2200 m in Triassic rocks. Drilling proceeded without significant problems.\r\nThe well was drilled with spud mud down to 818 m and with KCl / polymer mud\r\nfrom 818 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eThere was no indication of shallow gas in\r\nthe hole. The well proved a significant reservoir development in the\r\nKapp Toscana Group where 130 m sandstone with good reservoir properties was\r\nindicated. Top of Kapp Toscana Group, Stø Formation, was encountered at 1399 m.\r\nLogs and RFT showed a thin oil zone of 1 - 1.5 m from 1403.5 - 1405 m. Oil\r\nshows were seen from 1402.5 m down to 1435 m in sandstones. In the interval\r\n1405 -2200 pressure point measurements show a gradient of 1.14 SG, which\r\nindicate saline formation water. The Triassic Kobbe Formation was encountered\r\nat 2104.5 m. Gas was encountered in two thin sand intervals in the top of the\r\nKobbe Formation. The upper sand interval (2105.1 m to 2107.8 m) has an average\r\nlog porosity of 19 % and an average water saturation of 49 %.\u00A0 In the lower\r\nsand (2123.5 m to 2125.3 m) the corresponding values are 20.5 and 53,\r\nrespectively. Gas shows and weak oil shows were observed in thin sand intervals\r\ndown to 2140 m. One core was taken in the Hekkingen Formation cap rock from\r\n1360 to 1371 m. A second core was taken in the Stø reservoir\r\nsandstone from 1406 m to 1434 m. A total of thre","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"646","properties":{"OBJECTID":646,"wlbNpdidWellbore":1351,"wlbName":"2/8-12 S","wlbHistory":"\r\n\r\n\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 2/8-12 S was drilled on the eastern\r\nflank of the Middle and Late Jurassic "Mode" salt feature in a\r\nlocation ca 12 km north of the Valhall Field. The well was planned deviated to\r\navoid the Ekofisk-Emden gas pipeline. The objective of the well was to test the\r\nreservoir and possible hydrocarbon potential in the Late and Middle Jurassic\r\nsands in the deepest part of the Central Trough, determine the source rock\r\npotential and maturation as well as the Jurassic stratigraphy, and determine\r\nthe Late Cretaceous/Tertiary stratigraphy of the chalk section.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 2/8-12 S was spudded with\r\nStena Equipment semi- submersible installation Dyvi Stena on 7 November 1988\r\nand drilled to TD at a total depth of 5300 m in the Triassic Group. The\r\nwell was drilled with seawater down to 904 m, with seawater/PAC/PHPA from 904 m\r\nto 3360 m, with seawater/Low Lime fro 3360 m to 4024 m, and with\r\nfreshwater/Hoestadrill mud from 4024 m to TD. Shallow gas was encountered in sands\r\naround 930 meters. The well was stabilised with heavy mud, and there was no\r\ndamage or injuries. \u003c/p\u003e\r\n\r\n\u003cp\u003eA major normal fault cuts through the\r\nchalk section and caused major problems with lost circulation. Later\r\nbiostratigraphic analyses showed that most of the Hod Formation was faulted out\r\nin the well. The lower Cretaceous section was thicker than expected due to a\r\n241 m of unexpected Early Cretaceous limestone/dolomite (Tuxen Formation). The\r\nLate Jurassic shales of the Tyne Group was encountered at 4000 m and proved to\r\nbe 1191 m thick, which also was thicker than expected. It consisted of the\r\nMandal (42 m), Farsund (165 m) and Haugesund (985 m) Formations. The lithology\r\nof the group was generally silty claystone/shale with dolomite/limestone\r\nstringers. Organic geochemical analyses of cuttings proved very good source\r\nrock potential throughout the whole Group, with the better potential found in\r\nthe Mandal and Farsund Formations. Top of the","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"647","properties":{"OBJECTID":647,"wlbNpdidWellbore":1355,"wlbName":"25/2-12 A","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 25/2-12 was\r\ndesigned to drill the crest of a NNE-SSW trending westward tilting Jurassic\r\nfault block. The northern extension of this structure was drilled in 1975 by\r\nwell 25/2-4 in a down dip position to well 25/2-12. A 70 m hydrocarbon bearing\r\ncolumn was encountered in the Vestland Group. The Statfjord Formation was found\r\nwater bearing. The main objectives of well 25/2-12 were to appraise and test\r\nthe hydrocarbon discovery of the Middle Jurassic Vestland Group and to explore the\r\nStatfjord Formation up dip from well 25/2-4. Due to an unprognosed fault top\r\nVestland came in 112 m deeper than prognosed in 25/2-12. Hence, side track 25/2-12\r\nA was decided. The main purpose of the sidetrack was to explore the still\r\nuntested Vestland up dip to the West.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eAppraisal well\r\n25/2-12 A was sidetracked from 3099 m in well 25/12-2 on 17 November 1988 by\r\nthe semi-submersible rig West Vanguard and drilled to TD at 3865 m in the\r\nMiddle Jurassic Vestland Group. During drilling the string got stuck at 3692 m.\r\nDrilling was stopped at 3714 m, one metre above the Vestland reservoir. Fishing\r\nwas unsuccessful, and the string was cut at 3485 m. When tripping out the well\r\nstarted to flow. Several days were needed to control the well and finally a\r\ncement plug was set from bottom to 3528 m. The cement was dressed to 3612 m and\r\na 7" liner was set from 3600 m to 2927.5 m. After that the cement was\r\ndrilled out to 3612 m before commencing to drill the 5 7/8" section.\r\nDuring drilling the 5 7/8" phase the string got stuck several times, and\r\nfinally stuck at 3865 m. While jarring the well started flowing again. After\r\ncontrolling the well a 4 1/2" liner was set from 3863 m to 3562 m. Cement\r\nwas drilled out to 3830 m before logging. Due to the problems no open hole logs\r\nwere run in well 25/2-12 A; all logs were run behind casing and no fluid\r\nsamples were taken. No cores were cut. The sidetracked well 25/2-12 A was\r\ncompleted 6 April 1989 a","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"648","properties":{"OBJECTID":648,"wlbNpdidWellbore":1356,"wlbName":"35/11-3 S","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 35/11-3 S was drilled on a location\r\nca 20 km north-north-east of the Troll Field, and was designed to test multiple\r\ndeltaic sands in the Middle Jurassic Brent Group. Early Eocene turbidites and\r\nPaleocene channel fill deposits were secondary objectives. Reservoir sands were\r\nexpected in the Tarbert, Ness, Etive and Oseberg Formations. These were\r\nhydrocarbon bearing in the 35/11-2 well. The seismic anomaly at Middle Jurassic\r\nlevel was mapped with a 30.4 km3 closure, and the expected gross thickness was\r\n220 m. The site survey showed no strong indications of shallow gas. It was,\r\nhowever, thought possible that sands in the intervals 479 - 497 m, and 573 -\r\n634 m might be gas charged.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 35/11-3 S was spudded with\r\nthe semi-submersible installation Dyvi Stena on 27 June 1989 and drilled to TD\r\nat 4040 m in the Early Jurassic Statfjord Formation. The well was drilled\r\ndeviated below 2100 m. Drilling proceeded without significant problems.\r\nHowever, the FMT sampling program for the Jurassic was curtailed when hole\r\nconditions deteriorated, and both the FMT tool and drill pipe became stuck\r\nduring the final logging operation. The well was drilled with seawater and\r\nhi-vis pills down to 1010 m and with KCl/polymer mud from 1010 m to TD. No\r\nshallow gas was encountered.\u003c/p\u003e\r\n\r\n\u003cp\u003eNo reservoir rocks were encountered in\r\nthe Lower Eocene succession, but good sands were present in the Paleocene\r\n(Intra Lista sand). Top Draupne Formation shales came in at 2821 m. Then came\r\nthe Sognefjord Formation at 3081 m and the Heather Formation at 3096 m. The\r\nwell penetrated the Brent Group at 3431 m, 236 m deep to prognosis. Good\r\nquality sands were found in the Brent Group, but not as good as in the 35/11-2\r\nwell.\u003c/p\u003e\r\n\r\n\u003cp\u003eGas levels throughout the Tertiary and\r\nLate Cretaceous were low. Oil shows with abundant free oil in the mud system\r\nwere observed in limestones of the Early Cretaceous Rødby and Mime Formations\r\nand in sandstones ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"649","properties":{"OBJECTID":649,"wlbNpdidWellbore":1358,"wlbName":"33/12-7","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 33/12-7 was designed to drill the\r\nDelta structure, a tilted fault block on the Tampen Spur, and was the only\r\ncommitment well in licence 152. The primary objective was to test the\r\nhydrocarbon potential of the Brent group on the Delta structure. A secondary\r\nobjective was to explore the Statfjord Formation on the same structure. The\r\nwell was designed as a possible producer in case of a discovery. Shallow gas\r\nwas predicted at 375 m MSL, 415 m MSL, and possibly in sand lenses on an\r\nerosion surface at 456 m MSL. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 33/12-7 was spudded with the\r\nsemi-submersible installation Deepsea Bergen on 22 February 1989 and drilled to\r\nTD at 3703 m in Early Jurassic sediments of the Statfjord Formation. After drilling\r\n26" section to 384 m fifteen days rig time were spent trouble shooting and\r\nrepairing a leak in the BOP. Otherwise operations went without significant\r\nproblems. The well was drilled with seawater and gel down to 383 m, with\r\nNewdrill/PAC/seawater from 383 m to 3034 m, and with gel/lignosulphonate from\r\n3034 m to TD. No shallow gas was encountered in the well. \u003c/p\u003e\r\n\r\n\u003cp\u003eSands were encountered in the Tarbert,\r\nRannoch, Cook and Statfjord Formations. No shows of hydrocarbons were recorded\r\nwhile drilling, except for some residuals in the Cook Formation. Post-well\r\norganic geochemical analyses established that the Draupne Formation has\r\npotential for generation of oil and gas and that the Heather Formation has\r\npotential for condensate/light oil and gas. Draupne is immature and Heather\r\nmarginally mature in the well location. Tarbert and Cook Formations were\r\nanalysed for migrated hydrocarbons but no significant abundance were found.\u003c/p\u003e\r\n\r\n\u003cp\u003eOne core was cut in the interval 3041 m\r\nto 3057.5 m. No fluid sampling was attempted.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 27\r\nApril 1989 as a dry hole.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was performed.\u003c/p\u003e\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"650","properties":{"OBJECTID":650,"wlbNpdidWellbore":1360,"wlbName":"6407/7-4","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell \u003ca name=\"OLE_LINK2\"\u003e\u003c/a\u003e\u003ca\r\nname=\"OLE_LINK1\"\u003e6407/7-4 \u003c/a\u003ewas drilled on the Njord A-East structure in the\r\nsouthern part of the Halten Terrace. The Njord structure is located ca 30 km\r\nwest of the Draugen Field\u003c/span\u003e. The location was within a\r\ngentle ice berg plough mark with a trend southwest-northeast. The primary\r\nobjective was to establish the oil-water contact in the Tilje Formation. Secondary\r\nobjectives were to obtain a better mapping of the reservoir quality of the\r\nTilje Formation on the east flank, to test productivity and injectivity of the\r\nTilje Formation, and to appraise the down flank oil bearing potential and\r\nproductivity of the Ile Formation. Reservoir fluids including formation water\r\nshould be sampled. Boulders were expected at 395 m, and shallow gas from 509 -\r\n528 m and especially at 553 m.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eAppraisal well 6407/7-4 was spudded by\r\nthe semi-submersible rig Polar Pioneer on 11 January 1989 drilled to TD at 3211\r\nm in Early Jurassic sediments of the Åre Formation. Spudding was delayed due to\r\nsevere weather conditions causing the rig to drift 43 nautical miles off\r\nlocation. No shallow gas was encountered. Further periods of bad weather led to\r\nsome problems and WOW, but apart from this the drilling proceeded without\r\nsignificant problems. The well was drilled with spud mud down to 538 m and with\r\nKCl mud from 538 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well proved oil in sands of the Ile, Tilje,\r\nand Åre Formations. The Ile Formation had oil from 2873.5 to 2896 m with a net\r\npay of 14.8 m. The Tilje Formation had oil from 2972.5 m and down to 3120 m. Net\r\npay in the Tilje Formation was 89.5 m. From logs, cores, and DST data an OWC could\r\nbe placed at ca 3120 m in the Tilje Formation, while RFT data indicated a\r\ncontact at 3110 m. The CPI log also showed a thin oil zone between 3148 and 3153\r\nm in the Åre Formation. Weak shows (minor spotted blue-white to yellow white\r\ndirect and cut fluorescence) were seen on limestones at","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"651","properties":{"OBJECTID":651,"wlbNpdidWellbore":1365,"wlbName":"34/10-33 A","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 34/10-33 A is a sidetrack from appraisal\r\nwell 34/10-33, which found oil in a down-to situation in the Gullfaks South\r\nDiscovery. The main objectives were to locate the gas-oil contact in the\r\nTarbert Formation and the oil-water contact, which was not seen in the primary\r\nwell. Further objectives were to acquire more pressure data over the reservoir\r\nin order to evaluate if the pressure shift in the oil zone seen in the primary\r\nwell could be explained by tight faults and/or a lateral continuous barrier within\r\nin the Ness Formation, and also to test if the Tarbert and Ness formations were\r\nin a common pressure regime. Finally, the well should provide water samples\r\nfrom the Brent Group and gather information for an optimal placing of a\r\nhorizontal test well as a new sidetrack from well 34/10-33.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 34/10-33A was kicked off on 15\r\nDecember 1988 from the vertical well 34/10-33 at 2698 m. The sidetrack was\r\ndrilled to TD at 3851 m in the Middle Jurassic Rannoch Formation using the\r\nsemi-submersible installation West Delta.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eDue to severe technical problems during\r\ndrilling, the logging programme was not fulfilled, and several of the well\r\nobjectives could not be met. The well was drilled with\r\ngel/lignosulphonate/lignite mud from kick-off to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe Brent Group was encountered at 3347\r\nm. The logs showed a gas/oil contact at 3427 m (3295 m TVD MSL) in the Tarbert\r\nFormation and suggested an oil/water contact at ca 3625 m (3430 m TVD MSL) in\r\nthe Ness Formation. In addition the well encountered a thin hydrocarbon bearing\r\nsand layer 3040 m (3001 m TVD MSL) in the Draupne Formation. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo cores were cut in this well and n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"652","properties":{"OBJECTID":652,"wlbNpdidWellbore":1366,"wlbName":"7120/1-2","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eBlock 7120/1 is situated on the southern\r\nmargin of the Loppa High and is bisected by the east-west trending Southern\r\nLoppa High boundary fault, which separates the Loppa High from the Hammerfest\r\nBasin to the south. The main objective of well 7120/1-2 was two\r\nseismostratigraphically defined wedges (of inferred Aptian age) in a large\r\nfault-bound closure against the Loppa High. Additional objectives were provided\r\nby a lower wedge of inferred Hauterivian age and Early Jurassic/Late Triassic\r\nelastics truncated beneath the Base Cretaceous unconformity, both down dip from\r\nthe structural culmination.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well spudded with the\r\nsemi-submersible installation Ross Rig on 1 January 1989 and drilled to a total\r\ndepth of 2630 m in Late Triassic sediments of the Fruholmen Formation. No\r\nshallow gas was encountered at any depth. The rig had to be moved three times\r\ndue to problems with boulders that increased the hole inclination too much.\r\nRough weather conditions, with waves exceeding 16 m, delayed drilling with\r\nseveral days. The well was drilled with seawater and spud mud down to 617 m and\r\nwith KCl /Polymer mud from 617 m to TD. \u003c/p\u003e\r\n\r\n\u003cp\u003eWell 7120/1-2 penetrated two seismically\r\ndefined "wedges" which contained three distinct clastic packages. The\r\nuppermost wedge (Wedge I from1585 m to1826 m) was dated as Early to Middle\r\nAlbian in age, whilst the lower hydrocarbon-bearing wedge contains two units of\r\nlatest Ryazanian / Early Valanginian (Wedge IIa from1878 m to 1984 m) and\r\nEarly Volgian age (Wedge IIb from1984 m to 2138 m) respectively. These units\r\nhad not previously been penetrated on the Barents Shelf.\u003c/p\u003e\r\n\r\n\u003cp\u003eOil shows (direct fluorescence) was\r\nrecorded on cuttings and cores in several intervals below 1931 m. Based on DST,\r\nlogs, cores and RFT pressure measurements it was concluded that an oil column\r\nin excess of 90 m was encountered in Wedge IIa. Hydrocarbon saturations were\r\nconsidered reliable and although ave","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"653","properties":{"OBJECTID":653,"wlbNpdidWellbore":1367,"wlbName":"2/7-19","wlbHistory":"\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 2/7-19 is located ca 10 km west of\r\nthe Embla and Eldfisk fields in the southern Norwegian North Sea. The objective\r\nwas to test the Danian - Late cretaceous limestone, and sandstones of the Early\r\nCretaceous and Jurassic on a low relief structure. Well 2/7-19 was the third\r\nattempt to drill this prospect. The first two attempts, 2/7-17 and 2/7-18, were\r\njunked because of mechanical problems. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 2/7-19 was spudded with the\r\nsemi-submersible installation Borgny Dolphin on 2 September 1980 and drilled to\r\nTD at 4877 m in the Late Permian Zechstein Group. A total of 154 days on the\r\nlocation were used to drill and abandon the well. The well was drilled to a\r\ndepth of 4785 m with 16.0 ppg mud. This was on 17 November. An estimated 12 m\r\nof Early Cretaceous sandstone had been penetrated and the drilling gas had\r\nincreased after entering this zone, with some indications of hydrocarbons. The\r\nwell was static with 16.0 ppg density mud, however the weight was raised to come\r\nout of the hole and commence coring. Upon raising the mud weight to 16.3 ppg a\r\npack-off occurred which broke down a formation and circulation was lost.\r\nCirculation was re-established with 16.0 ppg mud. The mud weight was then\r\nraised in stages from 16.2 ppg to give an adequate trip margin to log. Logs\r\nwere run, after which lost circulation problems again occurred. It took up to\r\nJanuary 8 1981 before problems were cured and drilling could commence. The well\r\nwas drilled with seawater and pre-hydrated bentonite down to 593 m, with\r\nseawater/bentonite/native solids from 593 m to 1600 m, and with\r\nseawater/Drispac/lignosulphonate from 1600 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eNo hydrocarbons were encountered in the\r\nDanian - Late Cretaceous limestone. Some fluorescence was observed on limestones\r\nin the Tor Formation and in the Hidra Formation. Gas-bearing sands of the Ula\r\nFormation were encountered. Oil shows were recorded in these sands, generally\r\ndescribed as dull yellow flu","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"654","properties":{"OBJECTID":654,"wlbNpdidWellbore":1371,"wlbName":"2/4-15 S","wlbHistory":"\r\n\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThe primary purpose of well 2/4-15 S was\r\nto control and kill the underground blow out in well 2/4-14. Well 2/4-15 S was\r\nplanned deviated from a location ca 1 km south of the 2/4-14 location to\r\nintersect with the 2/4-14 well bore below the bottom hole assembly that had\r\nbeen left in this hole. The well would serve several possible uses: \u003c/p\u003e\r\n\r\n\u003cp\u003e- Assist in killing 2/4-14 below the BHA.\u003c/p\u003e\r\n\r\n\u003cp\u003e- To check and verify the extent of\r\nunderground pressure charging, zone isolation and underground blowouts, and to\r\ncure and verify possible cross flows.\u003c/p\u003e\r\n\r\n\u003cp\u003e- To serve as an emergency relief well to\r\ndynamically kill an uncontrolled blow out in well 2/4-14.\u003c/p\u003e\r\n\r\n\u003cp\u003e- To be used as an exploration well if\r\nthe top intervention was successful.\u003c/p\u003e\r\n\r\n\u003cp\u003eShallow gas was predicted at 611 m where\r\na seismic anomaly corresponds to a gas bearing sand layer in well 2/4-14\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat Relief well 2/4-15 S was spudded\r\n31 January 1989 by the semi-submersible installation Treasure Saga. The well\r\nwas spudded 1182 m south of the 2/4-14 spud location and drilled to 4962 m\r\nwhere it intersected with the 2/4-14 well bore. This point is recognized as TD\r\nof the well. The well was drilled with sea water/gel mud down to 920 m, with\r\nKCl mud from 920 m to 3867 m, and with Hi-Temp polymer mud from 3867 m to TD.\r\nShallow gas was encountered at 611 m as prognosed. Thin gas-bearing sands were\r\nseen on the resistivity MWD log also at 525 m and at 627 m. Drilling proceeded\r\nwith significant problems due to rich smectite content between 1800 and 2300 m.\r\nThe drill string got stuck twice, backed off, and after unsuccessful fishing,\r\ntechnical sidetracks were performed. On 1 May 1989, when drilling the 12\r\n1/4" section in well 2/4-15 S, well 2/4-14 was re-entered with the jack up\r\nrig Neddrill Trigon. Both wells were now involved in the killing operations\r\n(see well history for 2/4-14 R). When drilling 2/4-15 S at around 4962 m, just\r\nprior to pulling ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"655","properties":{"OBJECTID":655,"wlbNpdidWellbore":1375,"wlbName":"35/9-1","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 35/9-1 was drilled on the M ål øy\r\nSlope north of the Horda Platform. The drilled "A-structure" is an\r\nasymmetric horst with the larger fault to the east, antithetic to the Øygarden\r\nfault zone. The primary objective of well 35/9-1 was to test the hydrocarbon\r\npotential and reservoir quality in Middle Jurassic sandstones of the Brent\r\nGroup. Secondary objective was to test the hydrocarbon potential and reservoir\r\nquality in the Dunlin Group and Statfjord Formation. A third objective was to\r\ntest the prospectivity in Cretaceous fans, building out from the southeast. The\r\nwell would also test the cap rock properties as well as the possibility of any\r\nreservoir rocks in the Late Jurassic. The commitment was to drill to 4000 m, or\r\ninto Triassic rocks whatever came first. No shallow gas was predicted at the\r\nwell location.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 35/9-1 was spudded with the\r\nsemi-submersible installation Polar Pioneer on 1 April 1989 and drilled to TD\r\nat 2350 m in crystalline basement rock. In the 17 1/2" section the mud\r\nsystem became heavily contaminated from cement after the 13 3/8" casing\r\nhad parted between 1067 m and 1083 m. To cure this the 9 5/8" casing was\r\nrun and cemented inside the 13 3/8" casing. Otherwise no significant problems\r\nwere encountered in the operations. The well was drilled with seawater and\r\nhi-vis pills down to 815 m and with KCl/polymer mud from 815 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eNo sands were encountered within the\r\nEarly Cretaceous sequence. The Jurassic was found gas bearing from 2036.5 m in\r\nthe Viking Group, through the Brent Group, and with a somewhat uncertain\r\ngas/oil contact at 2282 m in the Early Jurassic Dunlin Group. An oil-down-to\r\ncontact was found at 2301 m in the Dunlin Group. The reservoir in the Viking\r\nGroup consisted of interbedded shales and sandstones of the Fensfjord,\r\nKrossfjord,and Heather Formations. RFT tests showed that there is no pressure\r\ncommunication between the Br","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"656","properties":{"OBJECTID":656,"wlbNpdidWellbore":1382,"wlbName":"1/2-1","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 1/2-1 is located in the Central\r\nGraben, about 200 m from the UK border in the North Sea. The main objective was\r\nPaleocene sands of the Rogaland Group. The secondary target was the chalk\r\nformations, although these were possibly not enough fractured to represent a\r\nreservoir. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 1/2-1 was spudded with the\r\nsemi-submersible installation Ross Isle on 20 March 1989 and drilled to TD at 3574 m in the Late Cretaceous Tor Formation. While cutting of core no 7, the\r\nelevators accidentally opened and dropped the string. Two attempts were made to\r\nrecover the string with no success. The hole was sidetracked from 3078.5 m and\r\ncore no 8 was cut. The well was drilled with seawater down to 645 m, with native\r\nmud (water mixed with clays from the borehole itself) from 645 m to1525 m, and\r\nwith seawater from 1525 m to TD. No shallow gas was detected in the hole.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe Forties Formation came in at 3121 m.\r\nThe formation was hydrocarbon bearing down to 3142.5 m as confirmed by both\r\nelectric logs and the RFT pressure gradient. The reservoir sandstones of the\r\nForties Formation showed good to excellent reservoir properties. Average core porosity\r\nwas 18.5% and test permeability was measured to 49 mD. \u003c/p\u003e\r\n\r\n\u003cp\u003eShows on cores were recorded down to core\r\n# 8 where they gradually decreased to zero at 3166 m. From the RFT data two\r\nwater gradients were identified below the oil zone. A shift of 8 psi between\r\nthem suggested the existence of an impermeable barrier around 3160.2 and 3162 m.\r\nCore saturations and fluorescence indicated the potential existence of a thin (4\r\nm) oil zone below this barrier. This zone was not identified from the logs and\r\nwas not evaluated for a test due to lack of data at that point. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe Ekofisk formation was encountered at\r\n3407 m, and the Tor formation at 3514 m. Both formations were water bearing.\u003c/p\u003e\r\n\r\n\u003cp\u003eA total of 8 cores were cut in the\r\nForties Formation, seven in the first hole and th","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"657","properties":{"OBJECTID":657,"wlbNpdidWellbore":1383,"wlbName":"2/8-13","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eExploration well 2/8-13 was designed to\r\ntest the Tertiary and Upper Cretaceous chalks overlying a salt induced domal\r\nfeature, unofficially named Mode, in the western part of block 2/8. The\r\nobjectives were to test the possible hydrocarbon accumulation contained within\r\nthe Tertiary and Upper Cretaceous chalks of the Ekofisk, Tor and Hod\r\nFormations; to determine the reservoir quality of the Shetland Group over the\r\nstructure; to determine the chalk stratigraphy over the Mode salt dome; and to\r\nacquire a VSP to help to image the chalk distribution and thickness over the\r\nMode feature.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was planned to penetrate the\r\nShetland Group on a structurally high at the northern flank of the Mode salt\r\nfeature. Shallow gas was expected at 507- 590- and 730 m.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 2/8-13 was spudded with the\r\nsemi-submersible installation Dyvi Stena on 28 April 1989 and drilled to TD at\r\n1940 m in the Permian Zechstein Group. The well was drilled with seawater / gel\r\n/ polymer down to 380 m, with PHPA/PAC mud from 380 m to 1253 m, with\r\nPHPA/PAC/ANCOMEL mud from 1253 m to 1457 m, with PHPA/PAC/NaCl mud from 1457 to\r\n1758 m, and with NaCl/PAC mud from 1758 m to TD. Shallow gas was encountered at\r\nthe prognosed depths, and controlled with heavy mud. Shallow gas encountered in\r\nsands at 828 m, caused the well to flow. The flow was killed with heavy mud,\r\nand caused no injuries or damages. The drill pipe got stuck, and had to be shot\r\nof above the BHA, which than was cemented in. The well was kicked off for the\r\n2/8-13 sidetrack at 412 m. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe Paleocene section was thinner than\r\nexpected, with Balder Sele and part of the Lista Formations missing. The gas\r\ncloud above the structure caused some difficulties as to predicting formation\r\ndepths and velocity correlations across the structure. The well drilled\r\ndirectly from Upper Cretaceous to Permian rocks. The Shetland Group came in 220\r\nm higher than prognosed and was 9.5 m thick, compared to p","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"658","properties":{"OBJECTID":658,"wlbNpdidWellbore":1384,"wlbName":"34/10-33 C","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 34/10-33 C is a sidetrack from\r\nappraisal well 34/10-33 B on the Gullfaks South Discovery. The B sidetrack was\r\ndrilled to perform a long-period test from a horizontal well through the upper\r\npart of the Brent Group, as part of the development of the Gullfaks South\r\ndiscovery. As the test in the B sidetrack failed the C-sidetrack was drilled\r\nwith the same main objectives, but this sidetrack was not to be drilled\r\nhorizontally. The test should provide information about requirement for pressure\r\nsupport during oil production, pressure communication in the gas cap during\r\nproduction, treatment of oil with high wax content, and it should collect\r\nliquid samples from the reservoir. Secondary objectives for the C sidetrack was\r\nto penetrate a complete Rannoch formation down flanks from well 34/10-33 and to\r\nestablish the oil/water contact in the lower part of the pressure regime\r\n(Etive/Rannoch formations). \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well 34/10-33 B was abandoned and an\r\nEZSV set at 3280 metres. Appraisal well 34/10-33 C was kicked off on 10 July\r\n1989 through the 9 5/8" casing from a Packstock tool set at 3279 metres in\r\nthe Tarbert Formation. The well bore was drilled with the semi-submersible\r\ninstallation Deepsea Bergen to TD at 3752 m (3587 m TVD) in the Early Jurassic\r\nDrake Formation. No significant problems occurred while drilling this well. The\r\nwell was drilled with Interdrill NT oil based mud from kick-off to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eFMT pressure points defined a gas/oil contact\r\nat 3302 m (3242 m TVD MSL) +/- 5 m and an oil/water contact at 3604 m (3460 m\r\nTVD MSL) +/- 20 m. Logs and sidewall cores indicated oil down to 3617 m (3467 m\r\nTVD MSL). Further shows evaluation from cuttings is uncertain due to oil based\r\nmud. The FMT measurements proved a ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"659","properties":{"OBJECTID":659,"wlbNpdidWellbore":1391,"wlbName":"6608/10-1","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 6608/10-1 is located on the Nordland\r\nRidge nearby the Revfallet Fault Complex. The primary objective of the well was\r\nto test a Turonian/Coniacian prospect in a position where Lysing sandstone was\r\nwithin defined closure. The well should also test the facies development of the\r\nEarly Cretaceous Fan, reservoir properties and formation pressure in the Middle\r\nJurassic, and the source rock potential of the Late Jurassic Spekk Formation\r\nand the Early Jurassic/Late Triassic Åre Formation. Planned TD was 3373 m, in\r\nthe coal bearing  Åre Formation. Prognosed sand layers in the interval 661 - 685\r\nm could be gas charged.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 6608/10-1 was spudded with\r\nthe semi-submersible installation Ross Rig on 15 April 1989 and drilled to TD\r\nat 3437 m in the Early Jurassic Åre Formation. No shallow gas was encountered\r\nwhile drilling and the well was drilled to TD without significant drilling\r\nproblems. The well was drilled with seawater and hi-vis pills down to 820 m,\r\nwith gyp/polymer mud from 820 m to 2508 m, and with gel/lingo mud from 2508 m\r\nto TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe main target was penetrated at 2661 m,\r\nbut proved to be only 1.5 m thick in the well position. There was no indication\r\nof hydrocarbons in the reservoir. The Lower Cretaceous Fan was penetrated in a\r\nvery distal position, and consisted of mudstone with thin sandstone stringers.\r\nThe Fangst group (Garn, Not and Ile Formations) was penetrated approximately\r\n100 m deeper than prognosed. All reservoirs were water bearing, but shows were\r\nrecorded in the Garn and Åre Formations. Post-well organic geochemical analyses\r\nshowed poor potential in the Cretaceous and Tertiary sections except for an\r\ninterval around 1580 m to 1670 m in Oligocene / Brygge Formation, where TOC in\r\nthe range 2-3 % and Hydrogen Indexes around 110 mg/g were measured. Good source\r\npotentials were proven in the Spekk and Åre Formations. A total of three cores\r\nwere cut in the well with 100 % recovery. The f","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"660","properties":{"OBJECTID":660,"wlbNpdidWellbore":1394,"wlbName":"2/7-21 S","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 2/7-21 S was drilled to appraise the\r\n"South Eldfisk structure", now known as the Embla Field, located in\r\nthe Central Graben of the North Sea. It was the third well drilled on the structure,\r\na pre-Cretaceous fault block forming the boundary between the Grensen Nose to\r\nthe west and the Feda Graben to the east. The primary objective was to test the\r\nsandstones that tested oil in the 2/7-9 and 2/7-20 wells. It was anticipated\r\nthat the proposed location would encounter reservoir quality sands similar in\r\nnature, thickness, and depth as in the 2/7-20 well. Closure of the structure is\r\nprovided by normal down faulting to the North, South and West. Closure to the\r\neast is by the Lindesnes Ridge reverse fault. Vertical sealing is provided by\r\nthe Early Cretaceous Shales. No shallow gas was expected in this area, and no\r\nmajor obstacles other than high formation pressure in the reservoir. If\r\nsuccessful, the well was planned to constitute a second drainage point for\r\nfuture field development. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eAppraisal well 2/7-21 S was drilled\r\ndeviated from a three-slot template located at the 2/7-20 well to a location\r\n1020 m to the southeast. The well was spudded on the 21st June 1989 and drilled\r\nusing the semi-submersible installation Ross Isle to a Total Depth of 5039 m\r\n(4706 m TVD RKB) in rhyolitic igneous rocks of probable Early Devonian age. The\r\nwell was drilled without significant problems, except for MWD failures. Shallow\r\ngas was encountered at 586.7 m but caused no problems. The well was drilled\r\nwithout problem using SOLTEX Actaflow water based mud down to 4232 m at the\r\nbase of the Cretaceous section, where 9 5/8" casing was set. The remaining\r\n8 1/2" and 5 7/8" hole sections in the well were drilled using Invermul\r\noil based mud. \u003c/p\u003e\r\n\r\n\u003cp\u003eOil-bearing reservoir quality sands were\r\nencountered at 4313 m. No definitive oil-water contact could be seen. The section\r\nconsisted of undefined lithostratigraphy of pr","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"661","properties":{"OBJECTID":661,"wlbNpdidWellbore":1395,"wlbName":"25/1-7 R3","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 25/1-7 was drilled on the main Frigg\r\nstructure close to the UK border. The Frigg Field was discovered by well 25/1-1\r\nin 1971. Production from the field started in 1977. A main objective of well\r\n25/1-7 was to establish a reference monitoring station for the production of\r\ngas from the Frigg Field. The objective of the re-entry 25/1-7 R3 was to log\r\nthe fluid contacts.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 25/1-7 R3 was re-entered with\r\nthe semi-submersible installation West Vanguard on 15 April 1989.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was logged (2050 - 1910 m) through\r\ncasing with a Thermal Neutron Decay (TDT) log to determine the fluid contacts. The\r\nlog found the gas/liquid contact at 1920.2 m, a 5.2 m rise of the water level\r\nsince May 1988.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was suspended on 16 April 1989 as\r\na gas appraisal well. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eTesting\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo drill stem test was performed.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"662","properties":{"OBJECTID":662,"wlbNpdidWellbore":1396,"wlbName":"25/1-8 SR3","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe Frigg Field was discovered by well\r\n25/1-1 in 1971 and set in production in May 1977. Well 25/1-8 S was drilled in\r\nthe summer of 1985 to monitor changes in gas/fluid contact, uncover\r\npermeability barriers and pressure gradients in the Frigg Formation, refine the\r\ngeological model, and provide ties for seismic interpretations. Before\r\nproduction started the Frigg Field fluid contacts were: OWC = 1955.9 m TVD MSL\r\nand GOC = 1948.2 m TVD MSL. In July 1985 in 25/1-8 S found the oil-leg to be\r\nall swept with the exception of a very thin oil-layer lifted to 1903.5 m TVD\r\nMSL, 2 m below the new gas/liquid contact, which was now a gas/water contact\r\n(GWC) at 1901.3 m TVD MSL. The objective of the third re-entry well 25/1-8 SR3\r\nwas to monitor further changes in the GWC.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 25/1-8 S was re-entered\r\n(25/1-8 SR3) with the semi-submersible installation West Vanguard on 1 April\r\n1989.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe GWC was found at 1897.5 m TVD MSL, the\r\nsame as in 25/1-8 SR2. This was a similar situation as in well 25/1-7 and\r\ncorresponding re-entries ca 2.5 km to the north. It showed that gas drainage\r\nwas blocked by shale barriers over large areas in the central parts of the\r\nfield.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo cores were cut and no wire line fluid\r\nsamples were taken.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was suspended on 6 April 1989 for\r\nlater re-entry and monitoring of the reservoir parameters. It is classified as\r\na gas appraisal well.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eTesting\u003c/span\u003e\u003c/b\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo drill stem test was performed.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"663","properties":{"OBJECTID":663,"wlbNpdidWellbore":1407,"wlbName":"34/10-33 B","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 34/10-33 B is a sidetrack from the\r\nvertical appraisal well 34/10-33 on the Gullfaks South structure. It was the\r\nfirst horizontal well ever drilled on the Norwegian continental shelf. The main\r\npurpose of the well was to perform a long period test from a horizontal well\r\nthrough the upper part of the Brent Group. The well should provide important\r\nproduction data and the results from the well should be used to calibrate the\r\nsimulation model for the reservoir and also to update the geological model for\r\nthis part of the Brent Group. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well was sidetracked 27 April\r\n1989 from the vertical at 1840 m, just below the 13 3/8" casing shoe. The\r\nwell was drilled with the semi-submersible installation Deepsea Bergen to TD at\r\n3942 m in the Late Jurassic Heather Formation. The well bore was drilled with\r\ngel/lignosulphonate mud from kick-off to 1864 m and with Interdrill NT oil\r\nbased mud from 1864 m to TD. The hole was approximately horizontal in the\r\ninterval 3670 - 3942 m. During setting of the 7" liner for testing of the\r\nhydrocarbon zone, the pipe got stuck and broke between the extension pipe and\r\ndrill string. Fishing was unsuccessful, and the planned test was therefore not\r\npossible. Plugging was performed, and Statoil informed NPD and the partners\r\nabout the alternatives for future operations. After evaluation of FMT data, it\r\nwas decided to go for a new sidetrack, 34/10-33 C.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe formation tops came in close to the\r\nprognosis. The Brent Group, top Tarbert Formation was encountered at 3215 m.\r\nSandstones of the Brent Group contained oil and gas. Due to lateral pressure\r\nbarriers the Tarbert Formation proved to be water bearing in the horizontal\r\npart of the well bore, although good oil shows were de","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"664","properties":{"OBJECTID":664,"wlbNpdidWellbore":1411,"wlbName":"7324/10-1","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 7324/10-1 was drilled on the Alpha\r\nstructure in the Maud Basin on the Bjarmeland Platform. The main objective was\r\nto test the hydrocarbon potential in a prospect at the Base Anisian level (Top\r\nKlappmyss Formation). The secondary objective was to test sandstones below the\r\nBase Smithian level (Top Havert Formation). In addition the well should test\r\nthe source rock potential in the Triassic, Base Snadd, and Base Kobbe\r\nFormations. Possible sand layers at 575 - and 695 m justified a shallow gas\r\nwarning at these levels. Planned TD was at 3400 m in Late Permian.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 7324/10-1 was spudded with\r\nthe semi-submersible rig Ross Rig 3 June 1989 and drilled to TD at 2919 m in\r\nthe Early Triassic Havert Formation. TD was set approximately 500 m higher than\r\nprognosed due to lost circulation problems in the interval 1800 m to 2626 m.\r\nThe well was drilled with seawater down to 558 m, with gypsum / polymer from\r\n558 m to 2289 m, and with gel / lignosulphonate from 2289 m to TD. No shallow\r\ngas was encountered.\u003c/p\u003e\r\n\r\n\u003cp\u003eMinor gas was encountered in the Kobbe\r\nFormation at 1607 m but the sandstones had very poor permeability and no RFT\r\nsamples were collected. The main target at Base Anisian/Klappmyss Formation at\r\n1767 m in the prognosis, proved to be an intra Anisian seismic marker\r\nencountered at 1822 m. At this level there was no reservoir developed, neither\r\nwas there any reservoir developed at the new Anisian seismic marker on 2272 m.\r\nThe secondary objective at top Havert Formation encountered at 2512 m had a\r\nlimited reservoir developed. Shows were recorded in the Snadd Formation from\r\n617 m to 692 m and 1150 m to 1186 m. Organic rich shales were encountered in\r\nSnadd, Kobbe, and Klappmyss Formations, but from organic geochemistry only a\r\nthin sequences in the Snadd Formation could be classified as good, possibly\r\noil-prone source rocks. These were: a carbonaceous shale at 989 m and a thin\r\nclay stone sequence at 1603 m t","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"665","properties":{"OBJECTID":665,"wlbNpdidWellbore":1413,"wlbName":"7/12-7 R","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 7/12-7 R is a re-entry of 7/12-7 on\r\nthe east flank of the Ula Field. Well 7/12-7 confirmed oil in the Ula Formation\r\nand was suspended as a possible water injector. The objective of the re-entry\r\nwas permanent plugging and abandonment\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 7/12-7 was re-entered with the\r\nsemi-submersible installation Vildkat Explorer on 15 May 1989.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was plugged and permanently\r\nabandoned on 22 May 1989.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eTesting\u003c/span\u003e\u003c/b\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo drill stem test was performed. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"666","properties":{"OBJECTID":666,"wlbNpdidWellbore":1415,"wlbName":"16/3-3","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 16/3-3 is located on the eastern\r\nmargin of the Utsira High in the North Sea. The primary objective of the well\r\nwas to test the reservoir and hydrocarbon potential of the Paleocene Heimdal\r\nsands in the Havørn Prospect. The prospect sands pinches out to the east and\r\nsouth combined with a structural dip to the northwest. The source kitchen was\r\nexpected to be the Late Jurassic Draupne Formation in the Southern Viking\r\nGraben. Top seal for the sands were prognosed to be the Late Paleocene- and the\r\nEocene marine shales.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 16/3-3 was spudded with the\r\nsemi-submersible installation Vildkat Explorer on 24 July 1989 and drilled to\r\nTD at 1566 m in the Late Cretaceous Tor Formation. No significant problems occurred\r\nduring the operations. The well was drilled with seawater down to 445 m and\r\nwith lignosulphonate/seawater and gel from 445 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eLate Cretaceous rocks were encountered at\r\n1488 m, underlying 1341 meters of Cenozoic claystones. The Late Cretaceous\r\nsediments (+ 78 m) consisted of white-creamy chalk. The Heimdal Formation sands\r\nwere absent. No reservoir intervals were penetrated. No shows were recorded. \u003c/p\u003e\r\n\r\n\u003cp\u003eNo cores were cut and no fluid samples\r\ntaken in this well.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 6\r\nAugust 1989 as a dry well.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was performed\u003c/p\u003e\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"667","properties":{"OBJECTID":667,"wlbNpdidWellbore":1416,"wlbName":"2/12-2 S","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 2/12-2 S is located just 400 m\r\nsouth-west of the 2/12-1 Freja discovery well. The Freja Discovery (named Mjølner\r\nup to 1998) lie in a complex faulted area in the North Sea between the Feda\r\nGraben to the west and the Gertrude Graben to the east, just north of the\r\nborder from Danish sector. The reservoir is very deep, ca 4900 m, and the\r\nreservoir pressure is one of the highest on the Norwegian continental shelf.\r\nWell 2/12-2 S was designed to drill on segment E in the Freja Discovery.\r\nSegment E is separated from segment A by a major fault. It was not known if\r\nthis fault is sealing or not. The main objective for the well was to test the\r\nmapped hydrocarbon in place in a Late Jurassic sand unit west of the 2/12-1\r\ncompartment. There was no secondary target level known at the time of planning.\r\nThe well was designed for further use as an oil producer and/ or for extended/\r\nlong term testing. Shallow gas was predicted at 467 m and 534 m.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 2/12-2 S was spudded with the\r\nsemi-submersible installation Mærsk Jutlander on 15 February 1990 and drilled\r\nto TD at 5757 m (5337 m TVD RKB) in rocks of Triassic age. A total of 73 days\r\n(34%) was counted as lost time in this well. It was drilled deviated from below\r\nthe 30" casing shoe, with kick-off at 219 m. Drilling proceeded with only\r\nminor problems down to planned TD for the 17 1/2" section at 2790 m. When\r\npulling out the string stuck at 2631 m. It was backed off at 2280 m, leaving a\r\nfish in the hole. The well was plugged back and sidetracked from 2102 m.\r\nDrilling commenced to 2800 m where the 13 3/8" casing was set. When\r\ndrilling out cement in the top 12 1/4" section the pipe stuck again and\r\neventually a second fish was left in the hole. A second technical sidetrack was\r\nperformed with kick-off between 2602 and 2632 m. A third incident of stuck pipe\r\noccurred at 3585 m, but this time the pipe was freed and drilling could\r\ncommence. After setting the 7" ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"668","properties":{"OBJECTID":668,"wlbNpdidWellbore":1419,"wlbName":"25/3-1","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 25/3-1 was designed to drill a\r\nnarrow NNW-SSE trending horst structure on the Utsira High. The main objective\r\nfor the well was to test the hydrocarbon potential of the Middle Jurassic Vestland\r\nGroup sandstones, and the Lower Jurassic Statfjord Formation sandstones. The\r\nsite survey indicated two high amplitude events at two different levels west\r\n(135 m MSL) and northwest (180 m MSL) of the proposed well location that could\r\nindicate shallow gas.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 25/3-1 was spudded with the\r\nsemi-submersible installation West Vanguard on 4 July 1989and drilled to TD at\r\n3922 m in Late Triassic sediments of the Statfjord Formation. To assure safe\r\noperation in possible shallow gas zones, the interval (198 to 720 m) was\r\ndrilled as a 17 1/2 " pilot hole before opening to 26" hole. Drilling\r\nwent on without any serious problems. No shallow gas was encountered. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe Vestland Group reservoir was reached 65\r\nm deeper than expected. The reservoir was thinner than expected, and of relatively\r\nbad quality and water bearing. The Statfjord Formation was reached 128 m deeper\r\nthan expected, and also water bearing. Very weak shows were recorded in two\r\nsamples from 2165 m and 2170 m in the Balder Formation; otherwise no shows were\r\nrecorded while drilling. Geochemical source rock screening found very good Type\r\nII kerogen (oil) source potential in the Draupne Formation and good Type II-III\r\nkerogen (gas + light oil) source potential in the Heather shales and the Vestland\r\nGroup coals and shales. The well has reached early maturity probably at ca 2700\r\nm, so the Draupne shale is in the very early oil window. \u003c/p\u003e\r\n\r\n\u003cp\u003eTwo cores were cut. Core no 1 was cut\r\nfrom 3112 to 3130 m in the Vestland Group, and no 2 from 3858 to 3876 m in the\r\nStatfjord Formation. The RFT tool was run, but due to obstruction in the hole\r\nrepresentative pressure points were not obtained. No fluid sample was taken.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"669","properties":{"OBJECTID":669,"wlbNpdidWellbore":1421,"wlbName":"30/9-8","wlbHistory":"\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 30/9-8 was drilled on the Oseberg\r\nOmega structure, which is located between the Gamma structure to the east and\r\nthe B structure to the west, and extends northwards into 079 license area. The\r\nmain target of the well was sandstones in the Middle Jurassic Brent Group. The\r\nprimary objectives were to prove the extension of the Omega oil column into\r\nlicense 104, find the fluid contacts, and test communication and reservoir\r\nrelationship with the Omega North and B prospects. The well was planned to\r\ndrill approximately 50 m into the Dunlin Group at a final depth of\r\napproximately 3182 m RKB.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 30/9-8 was spudded with the\r\nsemi-submersible installation Polar Pioneer on 29 July 1989 and drilled to TD\r\nat 1060 m in presumed Miocene sediments of the Hordaland Group. The well was\r\ndrilled using seawater and high viscosity pills with returns to the seabed. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo cores were cut and no wire line fluid\r\nsamples were taken.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAfter setting of the 13 3/8" casing\r\nto 1044 m the well was suspended on 2 August while the rig left for work on\r\nanother contract (TOGI pull-in operation). The well is classified as dry.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eTesting\u003c/span\u003e\u003c/b\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo drill stem test was performed.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"670","properties":{"OBJECTID":670,"wlbNpdidWellbore":1440,"wlbName":"2/4-14 R","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 2/4-14 R was designed to\r\nre-establish full well control of the uncontrolled flow in well 2/4-14 by using\r\nboth well 2/4-14 R and 2/4-15 S. The RKB with Neddrill Trigon is 37 m, but all\r\ndepths in this account are relative to the RKB of Treasure Saga (26 m) for\r\neasier comparison with other the well bores and re-entries involved in the blow\r\nout.\u003c/p\u003e\r\n\r\n\u003cp\u003eSince the underground blow out occurred\r\nin well 2/4-14 in January 1989 various surveys and analyses had been conducted\r\nto monitor any flow of gas into shallow strata in the area. Gas bubbles from\r\nthe site of the 2/4-13 well head were first time reported from ROV surveys in\r\nAugust 1989. A Sidescan Sonar Search was performed in the period from late June\r\n1989 up to late March 1990. No gas leakage was detected by this method. A\r\nseismic surveillance study was performed in the 2/4-14 area by Read Well\r\nServices A/S in order to monitor the noise and acoustic activity caused by\r\npossible cracking due to migration of hydrocarbons into the shallow sand\r\nlayers. Four seismometers were placed on the seafloor from 21 September to 2\r\nOctober 1989. Analysis of these data proved seismic activity, possibly due to\r\nthe pressure build-up and release of energy related to the hydrocarbon\r\naccumulation in the sand layers. Geochemical analyses of gas samples from wells\r\n2/4-13, 2/4-14, and 2/4-15 were conducted. Variable mixes of shallow (biogenic)\r\nwith deep reservoir (thermogenic) gasses were found in the samples, with the\r\nhighest proportion of thermogenic gas in the depression of well 2/4-13. Seismic\r\nshallow anomalies corresponding to sands at 828, 492 and 445 m were mapped in\r\nMarch 1990, indicating recipients for leaking hydrocarbons.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe 2/4-14 R well program covers the phase\r\nfrom where the 7" liner has been set, cemented, logged and successfully\r\npressure tested in well 2/4-15 S. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eJack-up rig Neddrill Trigon arrived the\r\n2/4-14 location on 21 March 1989. A sub sea snubbin","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"671","properties":{"OBJECTID":671,"wlbNpdidWellbore":1441,"wlbName":"35/9-1 R","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 35/9-1 R is a re-entry of well\r\n35/9-1, which found oil and gas in the Jurassic. Well 35/9-1 was suspended\r\nwithout testing due to other assignment for the rig. The objective for 35/9-1 R\r\nwas testing and permanent abandonment.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eAppraisal well 35/9-1 was re-entered\r\n(35/9-1 R) with the semi-submersible installation Polar Pioneer on 3 July 1989 \u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was tested, plugged, and\r\npermanently abandoned as an oil and gas appraisal.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThree DSTs were performed. Production\r\ntest data quoted below refer to maximum rates at the specified choke sizes.\u003c/p\u003e\r\n\r\n\u003cp\u003eDST 1 was performed in the interval\r\n2285.8-2291.8 m (Dunlin Group). It flowed at an oil rate of 903 Sm3/day through\r\na 25.4 mm choke. The GOR was 284 Sm3/Sm3. The oil gravity was 0.815 g/cc and\r\nthe gas gravity 0.705 (air = l). The wellhead pressure was 73.5 bars and the\r\nbottom hole temperature 79.9 deg C. The well produced no CO2 or H2S. The\r\nproduction index was 23.6 Sm3/day/bar.\u003c/p\u003e\r\n\r\n\u003cp\u003eDST 2 was performed in the interval 2225.4-2249.4\r\nm (Brent Group). It flowed at a gas rate of 598000 Sm3/day through a 17.46 mm\r\nchoke. The GOR was 3014 Sm3/Sm3. The oil gravity was 0.728 g/cc and the gas\r\ngravity 0.681 (air=l). The wellhead pressure was 150.6 bar and the bottom hole\r\ntemperature 78.2 deg C. The well produced 0.4% CO2 and no H2S.\u003c/p\u003e\r\n\r\n\u003cp\u003eDST 3 was performed in the interval\r\n2100.3 - 2138.3 m (Krossfjord Formation). It flowed at a gas rate of 912500\r\nSm3/day through a 25.4 mm choke. The GOR was 5098 Sm3/Sm3. The oil gravity was\r\n0.749 g/cc and the gas gravity 0.705 (air=l). The wellhead pressure was 116.5\r\nbars and the bottom hole temperature 74.2 deg C. The well produced 0.4% CO2 and\r\nno H2S.\u003c/p\u003e\r\n\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"672","properties":{"OBJECTID":672,"wlbNpdidWellbore":1442,"wlbName":"30/9-9","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 30/9-9 was drilled on the J-South\r\nstructure in the Oseberg Sør Field complex in the North Sea. The first well on\r\nJ-South, well 30/9-5 S some 3.5 km to the north, encountered a highly eroded\r\nBrent Group with gas shows in the Brent, a gas bearing Cook Formation and a\r\nwater bearing Statfjord Group. The primary objective of well 30/9-9 was to\r\nprove oil in the Brent Group and the Cook Formation, and define the oil-water\r\ncontact. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 30/9-9 was spudded with the\r\nsemi-submersible installation Polar Pioneer on 26 September 1989 and drilled to\r\nTD at 2809 m in the Early Jurassic Eiriksson Formation. No significant problem\r\nwas encountered in the operations. The well was drilled with seawater and\r\nhi-vis pills down to 919 m and with KCl/polymer mud from 919 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe Tarbert Formation and the uppermost\r\npart of the Ness Formation were found oil bearing down to 2319 m. The net pay\r\nwas estimated to be 13.5 m and average water saturation calculated to 30.1%. Average\r\nporosity was 20.8%. The Ness Formation (2307 - 2412 m) was found oil bearing\r\nfrom 2391.5 to 2412.5 m. No oil water contact was proved, leaving oil down to\r\nbase reservoir. The net pay was estimated to be 15.5 m and average water\r\nsaturation calculated to 24.3%. Average porosity was 24.9%. RFT results showed\r\nno pressure communication between the hydrocarbon bearing intervals in the\r\nTarbert and Ness Formations.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe Etive-Rannoch Formations and the\r\nOseberg Formation were not present in the well, most likely due to faulting.\r\nThe lower Jurassic Cook Formation and the Statfjord Group were found water\r\nbearing. Oil shows were described on claystones and sandstones from 2115 to\r\n2175 m, throughout the","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"673","properties":{"OBJECTID":673,"wlbNpdidWellbore":1443,"wlbName":"2/9-3","wlbHistory":"\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 2/9-3 was drilled on the Piggvar\r\nTerrace, between the Central Graben to the west and the Mandal High and the Søgne\r\nBasin to the east. The primary objective was to test for hydrocarbons, reservoir\r\nquality, and source rock potential and maturation in Late and Middle Jurassic formations.\r\nSecondary objectives were to determine the Permian stratigraphy in this portion\r\nof the Piggvar Terrace, and the reservoir quality and possible hydrocarbon\r\naccumulation in Early Permian Rotliegendes sands.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 2/9-3 was spudded with the\r\nsemi-submersible installation Dyvi Stena on13 September 1989. After drilling to\r\n378 m the hole packed off, and the well had to be re-spudded. The re-spud took\r\nplace 20 m from the original location on 15 September 1989 and the well was drilled\r\nto TD at 4859 m in the Early Permian Rotliegend Group. BHA component failures\r\nin the 12.25" and 8.5" hole sections accounted for 9.4 days of lost\r\ntime, but generally drilling and operations went without significant problems,\r\nand the well was drilled within the scheduled time. Possible shallow gas had\r\nbeen warned pre-drill at 160, 425 and 535 m, but no shallow gas was\r\nencountered. The well was drilled with seawater and hi-vis pills down to 850 m,\r\nwith KCl/PHPA/PAC mud from 850 m to 3875 m, and with HRM/polymer mud from 3875\r\nm to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe lowermost part of the chalk was of\r\nSantonian age. The Coniacian, Turonian and Cenomanian were apparently absent as\r\nthey where in well 2/9-2. A 12 m thick Early Cretaceous section was penetrated,\r\ndating Valanginian to Early Barremian. No evidence of Albian, Aptian and\r\nRyazanian was seen. Top Late Jurassic came in at 3846 m, close to prognosed\r\nd","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"674","properties":{"OBJECTID":674,"wlbNpdidWellbore":1444,"wlbName":"1/9-1 R","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 1/9-1 R is a re-entry of well 1/9-1\r\non a salt diapir structure located in the Feda Graben in the southern North\r\nSea. The purpose of the re-entry was permanent abandonment.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe suspended well 1/9-1 was re-entered\r\n(1/9-1 R) with the semi-submersible installation Ross Isle on 8 May 1987. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo cores were cut and no wire line fluid\r\nsamples were taken.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was plugged and permanently\r\nabandoned on 17 May 1987.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eTesting\u003c/span\u003e\u003c/b\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo drill stem test was performed.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"675","properties":{"OBJECTID":675,"wlbNpdidWellbore":1453,"wlbName":"31/2-16 S","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 31/2-16 S was drilled as an\r\nappraisal in the Troll-West Oil province in the Northern North Sea. It was\r\nlocated on the crestal part of the Oil Province close to well 31/2-5. The\r\nprimary objective was to drill hole and prepare for a long term production from\r\na horizontal well drilled 5 m above the oil/water contact in the 23.5 m thick\r\noil column. The length of the horizontal section should preferably be 500 m. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eAppraisal well 31/2-16 S was spudded with\r\nthe semi-submersible installation Deepsea Bergen on 27 September 1989 and\r\ndrilled to TD at 2390 m ( 1587 m TVD RKB) in the Late Jurassic Sognefjord\r\nFormation. The well was drilled vertical down to 1118 m in the 17 1/2"\r\nsection and kicked of from there, building angle up to a horizontal well path\r\nfrom ca 1950 m. Problems with tight hole, lost circulation and hard formation\r\n(stringers) were encountered repeatedly in the 17 1/2 and 12 1/4" sections\r\nfrom 1015 to 1891 m. The well was drilled with sea water and hi-vis pills down\r\nto 1015 m and with Versaport oil based mud from 1015 m to 1891 m, and with a\r\nsuper-saturated NaCl / polymer mud from 1891 m to TD. During well completion and\r\npreparation for production testing the screen-packer stuck at 570 m. Close to\r\neight days were lost in milling and retrieving the fish before normal\r\noperations could be resumed. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe Sognefjord Formation was encountered\r\nat 1659 m (1533 m TVD RKB). The established gas/oil contact in the Troll Field\r\nis at 1547 m MSL TVD, which is 1.5 m deeper than observed in this well. This\r\n1.5 m is within the uncertainty of the TVD calculations, and a common gas/oil\r\ncontact is assumed.\u003c/p\u003e\r\n\r\n\u003cp\u003eNo conventional or side wall cores were\r\ncut. No wire line pressure tests or fluid samples were taken. Apart from runs\r\n1A, wire line logging was performed by the use of pipe conveyed Logging\r\nSystems. MWD was the only deep resistivity measuring device through the whole\r\nwell.\u003c/p\u003e\r\n\r\n\u003cp\u003eAfter d","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"676","properties":{"OBJECTID":676,"wlbNpdidWellbore":1459,"wlbName":"25/2-13","wlbHistory":"\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 25/2-13 was drilled in the central\r\npart of the Viking Graben, east of the Frigg area. The block straddles the\r\neastern flank of the graben and the north-western part of the Utsira High. It\r\nwas the first appraisal well on the 25/2-5 discovery, which discovered oil in\r\ndifferent reservoirs of the Vestland Group and the Statfjord Formation. The\r\nstructure is a north-south trending horst, which is located on a terrace in the\r\nsouthern part of the block. Well 25/2-13 was drilled close to a major normal\r\nfault bounding the structure. The main objective was to evaluate the western\r\npanel. The well should test the fluid columns in both the Vestland Group and\r\nthe Statfjord Formation, obtain data for fluid characterisation and\r\nproductivity, and try to define the hydrocarbon contacts of the reservoirs.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 25/2-13 was spudded 6 June\r\n1989 by the semi-submersible installation West Vanguard drilled to TD at 3909 m\r\nin the Triassic Smith Bank Formation. The well was drilled to 13" 3/8\r\ncasing point (2043 m) without problems, but at 2178 m the bit got stuck and a\r\nsidetrack was needed. The sidetrack was kicked off from 2070 m. The first\r\nattempt failed, but the second was successful. During coring of the Vestland Group,\r\nthe core barrel was lost in hole and a second sidetrack was decided after\r\nunsuccessful fishing. This sidetrack was kicked off from 3306. The mud that was\r\nused in the Jurassic section (3318 - 3887 m) was an FCL type mud which was\r\nbased on fresh water with added bentonite, polymers, lignosulfonate and barite.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eTop Vestland Group came in at 3342 m as\r\nprognosed, and with mobile hydrocarbons in two layers; oil in the top ca 40 -\r\n60 m of the reservoir with an unclear OWC in the interval 3382 - 3415 m, a","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"677","properties":{"OBJECTID":677,"wlbNpdidWellbore":1460,"wlbName":"7228/2-1 S","wlbHistory":"\r\n\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 7228/2-1 S is located on the western\r\nmargin of the Nordkapp Basin close to the Nyslepp Fault Complex. It was\r\ndesigned to drill a large salt induced anticline that is bisected by a major\r\nnorth - south trending fault. Due to the large Triassic throw on the fault, the\r\nup-thrown and downthrown parts of the structure were thought to represent\r\nseparate prospects. The downthrown prospect seemed to have the thickest\r\naccumulation of Triassic Anisian/Early Ladinian deposits, and was the primary\r\nobjective of the well. Secondary objectives were other Middle/Upper Triassic\r\nand Jurassic sandstones. To be able to meet all obligations and at the same\r\ntime test the primary objective without leaving significant potential up-dip,\r\nthe well path was planned deviated at approximately 30 degrees in a\r\nnortheasterly direction along seismic line MN89-603. Several reflectors in the\r\ninterval 397 m to 593 m were thought to represent sand layers with possible\r\nshallow gas. The strongest amplitude anomaly was at 435 m. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 7228/2-1 S was spudded with\r\nthe semi-submersible rig Ross Rig 21 August 1989 and drilled to TD at 4300 m in\r\nthe Early Triassic Havert Formation. The well was deviated from 1475 m. At 2902\r\nm the bottom hole assembly was lost in the hole, and the well had to be\r\nsidetracked from 2700 m. The well was drilled with seawater and hi-vis pills\r\ndown to 1013 m, with KCl / polymer from 1013 m to 2206 m, with lignosulphonate\r\nfrom 2206 m to 3663 m, and with KCl / polymer from 3663 m to TD. No shallow gas\r\nwas encountered in the well.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eReservoir quality sands were found in the\r\nJurassic and uppermost Triassic Stø, Nordmela, Tubåen, Fruholmen, and Snadd\r\nformations. Of these the Nordmela and Tubåen sands had the best ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"678","properties":{"OBJECTID":678,"wlbNpdidWellbore":1461,"wlbName":"30/9-8 R","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 30/9-8 R was drilled on the Oseberg\r\nOmega structure, which is located between the Gamma structure to the east and\r\nthe B structure to the west, and extends northwards into 079 license area. The\r\nmain target of the well was sandstones in the Middle Jurassic Brent Group. The\r\nprimary objectives were to prove the extension of the Omega oil column into\r\nlicense 104, find the fluid contacts, and test communication and reservoir\r\nrelationship with the Omega North and B prospects. The well was planned to\r\ndrill approximately 50 m into the Dunlin Group at a final depth of ca 3182 m\r\nRKB. Well 30/9-8 R is a re-entry of well 30/9-8, which was suspended at 1060 m while\r\nthe rig left location temporary for another contract.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 30/9-8 was re-entered\r\n(30/9-8 R) by the semi-submersible rig Polar Pioneer on 15 August 1989. Cement and\r\nfloat collar was drilled from 1007 to 1060 m in 30/9-8. Well 30/9-8 R was then\r\ndrilled to TD at 3200 m in the Early Jurassic Drake Formation. Drilling\r\nproceeded without significant problems. There was no indication of shallow gas.\r\nThe well was drilled with a KCl/PAC/Polymer mud from 1060 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eTop reservoir came in at 2814 m,\r\napproximately 30 m deeper than prognosed. The reservoir was oil bearing from\r\n2824.5 to 2851 m. Below 2851 m the water saturation gradually increased. RFT\r\ndata indicated a free water level at 2856 m (2832.5 m MSL). However, the\r\navailable data do not permit the exact definition of the oil water contact,\r\nwhich is in the range 2856 -2862.5 m. The net pay was determined to be 22 m with\r\naverage water saturation calculated to 46%. Average porosity was 18.5%. RFT\r\nresults showed no pressure communication with well 30/9-4 within the Tarbert\r\nFormation. Well 30/9-8 is ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"679","properties":{"OBJECTID":679,"wlbNpdidWellbore":1467,"wlbName":"3/7-4","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 3/7-4 was designed to drill a\r\nprospect on the Lulita culmination. The Lulita prospect extends in to Danish\r\nwaters, and forms part of an elongated, N-S trending, salt induced feature on\r\nthe western margin of the Søgne Basin. The present structural features were\r\ndeveloped during mid Cretaceous time, and closure at Late Cretaceous and\r\nTertiary levels essentially reflects compaction and drape over the Jurassic\r\nhigh. The Jurassic Lulita closure is separated from the area tested by the\r\n3/7-3 well by a faulted saddle, which also is well expressed at Tertiary and\r\nCretaceous levels, providing a vertical closure of some 75 metres. The well had\r\nas primary objective to test the hydrocarbon potential of Middle Jurassic\r\nsandstones within a structural/stratigraphic trap, and as secondary objective\r\nto testing the potential in possible Late Jurassic and Early Cretaceous\r\nsandstones, within a structural trap. Additional objectives included testing of\r\nLate Cretaceous Chalk, found hydrocarbon bearing in the nearby Harald field,\r\nPaleocene/Eocene turbiditic sandstones, and the reservoir quality of the\r\nTriassic sequence. The well should drill some 150 m into rocks of Triassic age.\r\nShallow gas could be encountered at 317 to 388 m, at 485, and at 515 m according\r\nto seismic anomalies.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 3/7-4 was spudded with the\r\nsemi-submersible installation Hunter on 20 September 1989 and drilled to TD at\r\n3723 m in the Permian Zechstein Group. At 3472.9 m the string was backed off,\r\nand a cement kick off plug was set. The hole was sidetracked from 3405 m. The\r\nwell was drilled with seawater and hi-vis spud mud down to 622 m, with KCl\r\npolymer from 622 m to 3473 m, and with seawater/polymer from 3473 m to TD. No\r\nshallow gas was encountered.\u003c/p\u003e\r\n\r\n\u003cp\u003eA 160 m hydrocarbon column from top Ula\r\nFormation and down to 3572 m in the Bryne Formation was found from well-logs,\r\ncore shows, and RFT pressure gradients. Strong shows were recorded throughou","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"680","properties":{"OBJECTID":680,"wlbNpdidWellbore":1470,"wlbName":"7/12-9","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 7/12-9 was the ninth appraisal well\r\nto be drilled on the Ula Field in the North Sea. The primary well objectives\r\nwere to prove sufficient mobile oil in place in the SE-sector to support\r\nfurther development in this field area. In order to complete a full evaluation\r\nof the Ula Formation reservoir, the well was deepened with a 6" hole into\r\nthe lower reservoir zones 3B, 4 and 5, including about 50 m of the Triassic. A\r\nsecondary objective of this well was to be a possible future water injector\r\nshould development of this area proceed. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 7/12-9 was spudded with\r\nthe semi-submersible installation Ross Isle on 17 March 1990 and drilled to TD\r\nat 3820 m in the Triassic Skagerrak Formation. After the 30" conductor was\r\nset at 166 m, a 17 1/2" pilot hole was drilled without riser to 950 m.\r\nShallow gas was observed between 677 - 680 m. No significant problem was\r\nreported from the operations. The well was drilled with spud mud down to 1008\r\nm, with Petrofree mud down to 3684 m, and with Aker oil based mud from 3684 m\r\nto TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe Ula Formation came in at 3701 m, 20.5\r\nm shallower than predicted. The thickness was 58.5 m, which was 20.5 m thinner\r\nthan expected. The uppermost reservoir zones were absent in the well. Wire line\r\nlogging, RFT pressure measurements fluid samples proved oil down to ca 3735 m,\r\nand that the lowermost Ula Formation and the Triassic section were water\r\nbearing. Virgin pressure conditions were confirmed below 3750 m (Ula reservoir\r\nzones 4 and 5).\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eOne core was cut from 3689 m in the\r\nlowermost Farsund Formation to 3721.5 m in the middle of the Ula Formation\r\nreservoir zone 2B. The cored interval was 32.5m with 100% recove","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"681","properties":{"OBJECTID":681,"wlbNpdidWellbore":1477,"wlbName":"2/7-14 R","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 2/7-14 R is a re-entry of well\r\n2/7-14 on the southern nose of the Ekofisk Field. The 2/7-14 well was drilled\r\nand suspended in 1980, after having confirmed oil in the Ekofisk and Tor\r\nFormations. The objective of the re-entry was plugging and permanent\r\nabandonment.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 2/7-14 was re-entered (2/7-14 R)\r\nwith the semi-submersible installation Ross Isle on 7 June 1989. \u003c/p\u003e\r\n\r\n\u003cp\u003eIt was plugged and permanently abandoned\r\non 19 June 1989.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was performed.\u003c/p\u003e\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"682","properties":{"OBJECTID":682,"wlbNpdidWellbore":1479,"wlbName":"6205/3-1","wlbHistory":"\u003cb\u003e\r\nGeneral\r\n\u003c/b\u003e\r\n\u003cp\u003e\r\nWell 6205/3-1 is situated in the northern part of the block on the B-prospect, which is an easterly tilted fault block bounded to the west by a northeast-southwest trending normal fault. The reservoir sequences are truncated at the crest of the fault block. The license area is bounded to the east and south by the Møre-Trøndelag Fault Zone, and to the north by the Jan Mayen fracture zone and the Frøya High. The Gossa High is situated in the western part of the license area at the western boundary of the Møre Basin. Well 6205/3-1 was the first obligation well to be drilled in license 154, and the first to be drilled in the Møre area. No direct correlation to the Haltenbanken or northern North Sea was possible. While the commitment was to drill to 4500 m or to Triassic sediments whichever came first, total depth was planned at 5100 m in Jurassic rocks of the Båt Group. The primary objectives for the well 6205/3-1 were to prove oil in the Jurassic sandstones and to verify the structural and sedimentological inte\r\n\u003c/p\u003e\r\n\u003cb\u003e\r\nOperations and results\r\n\u003c/b\u003e\r\n\u003cp\u003e\r\nWell 6205/3-1 was spudded on 24 October 1989 with the semi-submersible rig \"Mærsk Jutlander\" and re-spudded on 29 October after high angle had developed in the surface hole. A kickoff was carried out at 2800 m using bent sub and motor from 2800 to 2886 m in two bit runs due to problems in receiving tool face from MWD. Apart from some experiences with tight hole, drilling went on without any significant problems. The well was suspended at 4300 m in the Lower Cretaceous Åsgard Formation on 11 February 1990 because of environmental restrictions, which prohibited drilling through any formations containing hydrocarbons after 15 February. None of the objective horizons were penetrated. The well was re-entered on 20 September 1990 and was thereafter designated 6205/3-l R. The bottom of the rathole below the 9 5/8\" shoe was encountered 6 m high at 4294 m. The well was drilled to TD of 5264 m on 6 November 1990. The well bores were drilled with sp","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"683","properties":{"OBJECTID":683,"wlbNpdidWellbore":1486,"wlbName":"7228/9-1 S","wlbHistory":"\r\n\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 7228/9-1 S is located on the\r\nwestern margin of the Finnmark Platform in the Nordkapp Basin South. The\r\nobjective of the well was to test the Jurassic and Triassic prospects above the\r\nsalt with the Early Triassic Klappmyss Formation as the primary target. Further\r\nobjectives of this wildcat well was to obtain stratigraphic information from\r\nthe Palaeozoic for future exploration in the area and to gather as much\r\ngeological information as possible regarding reservoir, source and cap rock\r\nintervals. The well position was chosen to leave a minimum of untested\r\npotential up-dip from the well location and to avoid faults that could disturb\r\na good seismic tie. Total depth was planned to 300 m below the base Sakmarian\r\nreflector, but not deeper than 4960 m. If massive evaporites were encountered\r\nbelow the Base Sakmarian reflector, drilling would terminate within 50 m. The\r\nwell would be deviated from approximately 2300 m in direction 270 deg to avoid\r\nmajor faults and to test potential reserves up-dip. No shallow gas was expected\r\nin the well.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well is Type Well for the Ulv\r\nFormation and Reference Well for the Røye and Ørret formations.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 7228/9-1 S was spudded with\r\nthe semi-submersible rig Ross Rig 22 December 1989. Due to severe difficulties\r\nwith tight hole in the top-hole section, the well was re-spudded twice. The\r\nprimary reason for the problems was the extremely reactive swelling clay.\r\nExposed to water, the clay swelled without space to expand and thereby raise\r\nthe formation pressure. The well was drilled to TD at 4576 m in Early Permian\r\nevaporites. No shallow gas was observed in the well. The well was drilled with\r\nseawater and CMC hi-vis pills down to 958 m, and with KCl/polymer mud f","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"684","properties":{"OBJECTID":684,"wlbNpdidWellbore":1488,"wlbName":"25/5-3","wlbHistory":"\r\n\r\n\u003cp\u003eWildcat well 25/5-3 is located on the\r\nUtsira High, ca 15 km south-south-east of the Frøy Field in the North Sea. The\r\nmain target was a prospect at Middle Jurassic level. Early Palaeocene\r\nsandstones and Early Jurassic Statfjord sandstones were secondary targets. For\r\nall targets the expected fluid was oil.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 25/5-3 was spudded with the\r\nsemi-submersible installation West Vanguard on 27 January 1990 and drilled to\r\nTD at 2900 m in the Triassic Group. No significant problems were\r\nencountered in the operations. The top hole down to 200 m was drilled with sea\r\nwater. The reservoirs were drilled with sea water / KCl / polymers.\u003c/p\u003e\r\n\r\n\u003cp\u003eTwo massive, clean, sandstone intervals (22\r\nand 61 m) were found between 2211 and 2310 m in the basal Tertiary (Ty\r\nFormation). The sands were separated by a shaly layer and were water bearing\r\n(no shows at all). The Vestland Group reservoir was 69 m thick (2384-2453 m) and\r\nconsisted of sandstones, generally fine grained, clean, occasionally\r\nmicaceous/shaly and calcareous cemented. It was gas-bearing at top (gas column\r\n42 m). The gas-water contact was found at 2426 m, based on logs and RFT\r\npressures. Oil shows were observed on two sidewall cores at 2425 and 2428.7 m,\r\nbut the amount of hydrocarbons (Iatroscan) obtained by geochemical studies were\r\nvery low. No evidence of an oil zone could be seen on the RFT plot. The upper\r\n21 m had very good reservoir qualities with porosities above 25%, and average horizontal\r\nand vertical permeabilities of Kh = 363 mD and Kv = 236 mD, respectively. The\r\nbasal part had porosities around 20 %. For the total Brent the N/G was ca 77 %.\r\nThe Statfjord Formation was 139 m thick (2613-2752 m) and consisted of alternating\r\nsandstones and shales. The N/G was around 63 % with an average porosity of 25 %\r\nfor the reservoir levels. Some sandy levels had very good petrophysical characteristics\r\n(permeabilities above one Darcy). These reservoirs were water bearing. Apart\r\nfrom the two questiona","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"685","properties":{"OBJECTID":685,"wlbNpdidWellbore":1492,"wlbName":"7/7-1","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 7/7-1 was the first well in license\r\n148, and was designed to drill a tilted block on the Jæren High close to the UK border. Early/Middle Jurassic events resulted in uplift and erosion, such that Jurassic\r\nsediments at the well location are missing. Due to the Tertiary uplift and\r\neastward tilting of the Shetland Platform, along with a relative drop in sea\r\nlevel, this tilting gave rise to an eastward drainage pattern. Submarine fan\r\nsandstones derived from deltaic and barrier bar complexes in the Morray Firth\r\narea were deposited in the Central Graben and on to the Jæren High. Several\r\nlobe systems developed, giving rise to continuous and periodic sandstone\r\ndeposition as the lobes migrated laterally. The eastern pinch out of these systems\r\noccurs in blocks 7/4 and 7/7. The primary objective of this well was an\r\nanticlinal closure at the Base Cretaceous Unconformity level, the C-prospect,\r\nTriassic sandstones. The secondary objective was the B-prospect, Paleocene\r\nsandstones, a possible closure along a pinch out of a sandy sequence consisting\r\nof distal turbidites. Some high amplitude anomalies indicated shallow gas\r\nbetween 241 to 395 m. The nearest one at 308 m was situated approximately 300 m\r\neast of the well location. Sticky and swelling "gumbo" clays are\r\ncommon in the area.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 7/7-1 was spudded with the\r\nsemi-submersible installation Deepsea Bergen 30 December 1989 and drilled to TD\r\nat 3500 m in the Triassic Smith Bank Formation. The well was drilled with seawater\r\nand gel down to 572 m, with gypsum/polymer mud from 572 m to 3263 m, and with\r\nbentonite/lignosulphonate mud from 3263 m to TD. Apart from some tight hole\r\nproblems, drilling went without severe problems. No shallow gas was\r\nencountered. The well was drilled approximately 200 m into the Triassic, which\r\nconsisted of brick red sandstones, interbedded with siltstone / claystone. The\r\nPaleocene sandstones came in nearly 60 m below the prognose","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"686","properties":{"OBJECTID":686,"wlbNpdidWellbore":1494,"wlbName":"25/7-2","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNorwegian\r\nContinental Shelf Block 25/7 is located west of the Utsira basement High on the\r\neastern flank of the Southern Viking Graben. The location is 5.3 km southwest\r\nof 25/7-1 which drilled into basement after the Cretaceous section without\r\npenetrating any Jurassic sediments and thus failed to test its target, Late\r\nJurassic sandstones. With the 25/7-2 location further to the west one expected\r\nto penetrate a complete Brae analogue sequence. The main objectives of the well\r\nwere to test the hydrocarbon potential of the Late Jurassic sands, the\r\nhydrocarbon potential of a structural closure at the Middle Jurassic sand\r\nlevel, and the hydrocarbon bearing potential of the Paleocene Heimdal sands.\r\nTrapping at Late and Middle Jurassic was assumed by sealing basement rocks to\r\nthe east, and by dip closure elsewhere. Events interpreted as possible gas\r\nbearing sands occur between 200 and 300 m below sea level.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 25/7-2\r\nwas spudded 8 February 1990by the semi-submersible rig Dyvi Stena, and\r\ncompleted 18 July 1990 at a depth of 4850 m in the Middle Jurassic Sleipner\r\nFormation. The well was drilled with Seawater and hi-vis pills down to 1220 m\r\nand with KCl Polymer WBS/200 mud from 1220 m to TD. Drilling took 131 days from\r\nspud and 142 days from taking over the rig. A further 29 days were used to log,\r\ntest, and plug and abandon the well. The rig was on contract for a total of 171\r\ndays. One hundred and thirty days were used for planned operations while\r\nwait-on-weather, fishing operations, and equipment trouble accounted for the\r\nNPT. No indications of shallow gas were observed. \u003c/p\u003e\r\n\r\n\u003cp\u003eForty-seven metres\r\nof Cenomanian sand was encountered in the well. A gross thickness of 174 meters\r\nof hydrocarbon bearing Late Jurassic conglomerates and sandstones were\r\nencountered in the well. The Late Jurassic conglomerates and sandstones\r\nrepresent deposition by debris-flows, slumps and slides and minor turbidites on\r\na fault-scarp ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"687","properties":{"OBJECTID":687,"wlbNpdidWellbore":1495,"wlbName":"2/7-22","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 2/7-22 was\r\ndesigned to drill a Late Jurassic prospect as the first commitment well in\r\nlicense 145.The prospect was a structural play defined at an intra-Jurassic\r\nlevel, located to the south-west of the Eldfisk South oil field in the Central\r\nGraben. A number of alternative outcomes were modelled to describe the\r\nuncertainty in the geological model. The most likely outcome predicted, was for\r\na Jurassic non-marine reservoir section. The large vertical relief of the\r\nstructure (550 m) also permitted the possibility of an additional lower\r\n(Permian) reservoir section. An extensive sidewall-coring program was designed.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 2/7-22\r\nwas spudded 17 May 1990 by the semi-submersible installation Ross Isle and\r\ncompleted 15 October 1990 at a depth of 4750 m in interbedded sandstones and\r\nmudstones of indeterminate pre-Jurassic age. The well thus fulfilled the\r\ngeological commitment. The well was drilled with seawater and hi-vis pills down\r\nto 1092 m, with ester based Petrofree mud from 1092 m to 2970 m, and with\r\nEnviromul oil based mud from 2970 m to TD. No shallow gas was encountered in\r\nthe well. No conventional cores were cut. Due to hard formation sidewall core\r\nrecovery was poor, and for recovered sidewall cores the depths are uncertain\r\ndue to technical problems. The well was a gas discovery having encountered a 14\r\nm pay zone in clean sands of indeterminate age with a hydrocarbon column being\r\nsmaller than prognosed. A gas/water contact was encountered at 4502 m. The\r\ntotal reservoir thickness is 66.5 m. The Late Jurassic Mandal formation came in\r\n218 m deeper than prognosed. One was tentatively trying to date the rocks below\r\nthe Jurassic sequence, but these rocks are classified as indeterminate. The\r\nreservoir rocks are probably an analogue to the Embla alluvial fan complex.\r\nWireline RFT samples were taken at 4494 and 4547 m. The well was permanently\r\nplugged and abandoned as a gas/condensate discovery.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTe","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"688","properties":{"OBJECTID":688,"wlbNpdidWellbore":1497,"wlbName":"6407/10-2","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 6407/10-2 was drilled on the B-II\r\nstructure south-east of the Njord Field, and is characterized by a prominent\r\nhanging wall anticline and syncline off the Trøndelag Platform and shows little\r\ntectonic disturbance as seen on seismic sections. From tectonic model inferred\r\nin the area, the tectonic damage to the reservoir rocks was expected to be less\r\nthan previously encountered in the A-Central and the A-North areas. Movements\r\nalong the main fault during the Late Jurassic caused sedimentation of Triassic\r\nand / or Middle and Early Jurassic clastics of delta fan type. Source rock for\r\nB-II area was prognosed to be the mature part of the Spekk Formation. Possible\r\nshallow gas might be present some 30 - 40 m below sea level. One core would be\r\ntaken in each of the Garn, Ile and Tilje formations. The main objectives for\r\nthe well were to asses the reservoir quality and hydrocarbon potential of the\r\nGarn, Ile, and Tilje Formations and the Late Jurassic sequence; to obtain\r\nreservoir pressure; confirm the seismic and geological model; and to asses the\r\npresence of sands in the Early Cretaceous sequence.\u003c/p\u003e\r\n\r\n\u003cp\u003ePrognosed TD was 3700 m in the upper part\r\nof the Tilje Formation, or alternatively 4040 m in Triassic rocks.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 6407/10-2 was spudded with\r\nthe semi-submersible rig Vildkat Explorer on 3 May 1990 and drilled to TD at\r\n3825 m in the Early Jurassic Tilje Formation sandstones. The well was drilled\r\nwith seawater and hi-vis pills down to1070 m and with KCl/Polymer/Polyacrylamide\r\nmud system from 1070 m to TD. In the 17 1/2" section 1070 to 2188 m mud\r\nfrom a previous well was used, below 2188 m fresh mud was used. Apart from some\r\ndifficulties during logging, drilling went on without any significant problems.\r\nNo shallow gas was encountered in this well. Apart from 8 m Lysing sand at 2378\r\nm there was no significant sand body development in the Cretaceous succession.\r\nThe Garn Formation was not present in the we","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"689","properties":{"OBJECTID":689,"wlbNpdidWellbore":1508,"wlbName":"1/6-5","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 1/6-5 is located in the Feda Graben\r\nbetween the Flyndre and Tommeliten Gamma discovery in the North Sea. The well\r\nwas drilled on the crest of a major salt diapir. The objective of the well was\r\nto test the existence of a chalk raft and the presence of reservoired\r\nhydrocarbons.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 1/6-5 was spudded with the\r\nsemi-submersible installation Dyvi Stena on 20 July 1990 and drilled to TD at 1854\r\nin Late Permian salt of the Zechstein Group. An 8 1/2" pilot hole was\r\ndrilled from 156m to 600m. The hole was control drilled at 30m/hr maximum ROP\r\nas a precaution for encountering shallow gas. No shallow gas was encountered. Pore\r\npressure prediction while drilling in the 1/6-5 well was difficult as the only\r\npore pressure detection parameters that appeared to work were gas measurements,\r\nresistivity and sonic log measurements. Other parameters such as shale cuttings\r\ndensity, Electric log density, D-exponent and rate of penetration were not\r\nsuccessful in determining high pore pressure zones. However, despite the\r\nabnormally high pressures and temperatures encountered drilling went forth\r\nwithout major incidents. A minor salt water flow accompanied by a 37.1 % gas\r\npeak occurred during a trip at core point at 1725 m. The mud weight was\r\nincreased from 15 ppg to 15.3 ppg and finally 15.5 ppg as a result of this flow.\r\nIn the following coring 119 bbls of mud was lost to the formation, but this was\r\ncured by setting an LCM pill. The well was drilled with seawater and viscous pre-hydrated\r\nbentonite sweeps down to 600 m and with fresh water polymer mud/Duponol WBS 200\r\nwellbore stabilizer from 600 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eFrom 864 m gas readings showed all\r\ncomponents from C1 to C4. Gas peaks from the formation were experienced all","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"690","properties":{"OBJECTID":690,"wlbNpdidWellbore":1510,"wlbName":"6205/3-1 R","wlbHistory":"\u003cb\u003e\r\nGeneral\r\n\u003c/b\u003e\r\n\u003cp\u003e\r\nWell 6205/3-1 is situated in the northern part of the block on the B-prospect, which is an easterly tilted fault block bounded to the west by a northeast-southwest trending normal fault. The reservoir sequences are truncated at the crest of the fault block. The license area is bounded to the east and south by the Møre-Trøndelag Fault Zone, and to the north by the Jan Mayen fracture zone and the Frøya High. The Gossa High is situated in the western part of the license area at the western boundary of the Møre Basin. Well 6205/3-1 was the first obligation well to be drilled in license 154, and the first to be drilled in the Møre area. No direct correlation to the Haltenbanken or northern North Sea was possible. While the commitment was to drill to 4500 m or to Triassic sediments whichever came first, total depth was planned at 5100 m in Jurassic rocks of the Båt Group. The primary objectives for the well 6205/3-1 were to prove oil in the Jurassic sandstones and to verify the structural and sedimentological inte\r\n\u003c/p\u003e\r\n\u003cb\u003e\r\nOperations and results\r\n\u003c/b\u003e\r\n\u003cp\u003e\r\nWell 6205/3-1 was spudded on 24 October 1989 with the semi-submersible rig \"Mærsk Jutlander\" and re-spudded on 29 October after high angle had developed in the surface hole. A kickoff was carried out at 2800 m using bent sub and motor from 2800 to 2886 m in two bit runs due to problems in receiving tool face from MWD. Apart from some experiences with tight hole, drilling went on without any significant problems. The well was suspended at 4300 m in the Lower Cretaceous Åsgard Formation on 11 February 1990 because of environmental restrictions, which prohibited drilling through any formations containing hydrocarbons after 15 February. None of the objective horizons were penetrated. The well was re-entered on 20 September 1990 and was thereafter designated 6205/3-l R. The bottom of the rathole below the 9 5/8\" shoe was encountered 6 m high at 4294 m. The well was drilled to TD of 5264 m on 6 November 1990. The well bores were drilled with sp","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"691","properties":{"OBJECTID":691,"wlbNpdidWellbore":1512,"wlbName":"2/7-19 R","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 2/7-19 R is a re-entry of well\r\n2/7-19, which was drilled in 1980/81 by the semi-submersible Borgsten Dolphin.\r\nThe well encountered gas in Early Cretaceous sandstones, but was suspended in\r\nFebruary 1981 due to a BOP system that was not rated to allow a DST test to be\r\nperformed. RFT tests measurements indicated a possible wellhead pressure of\r\n11200 psi, while the BOP was rated to 10000 psi. A 7" liner was run to a\r\ndepth of 4839 m and cemented, but not perforated. The purpose of the re-entry\r\nwas to test 43 m of gross pay distributed in four sand lenses from 4712 to 4839\r\nm. The DST test was designed such that it would be possible to keep the well\r\nfor future production if flow rates were commercial.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 2/7-19 was re-entered\r\n(2/7-19 R) with the semi-submersible installation Ross Isle on 15 January 1990.\u003c/p\u003e\r\n\r\n\u003cp\u003eDuring drilling of the 2/7-19 well, only gas\r\nwas encountered. The test in the re-entry showed that the reservoir rocks were\r\ntight, but a positive feature was that oil was encountered during testing. The\r\ntest confirmed the earlier anticipated formation pressure of 860 to 895 bar. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 14\r\nMarch 1990 as an oil appraisal.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eOne DST test was performed from four sand\r\nlenses in the intervals 4712 - 4727 m, 4762 - 4783 m (Ula Formation), 4800 -\r\n4818 m Ula/Bryne Formations), and 4830 - 4838 m (Bryne Formation). The total\r\nnet pay in the perforated sections was 23 m. After acid treatment the well\r\nproduced hydrocarbons at a rate of 34.8 Sm3 oil and 15631 Sm3 gas /d through an\r\n11.91 mm choke. The CO2 content of the separator gas was 4.4%. The GOR was 449\r\nSm3/Sm3 but this figure is uncertain due to slugging of the well and poor rate\r\nmeasurements. The matrix/acid job performed was not effective. The stable\r\nshut-in temperature at 4628 m (gauge depth) was 169 deg C, while maximum\r\nrecorded flowing temperature was 172 deg C. It wa","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"692","properties":{"OBJECTID":692,"wlbNpdidWellbore":1513,"wlbName":"6407/7-2 R","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 6407/7-2 R is a re-entry of well\r\n6407/7-2 on the Njord Discovery. The purpose of the re-entry was to conduct a\r\nlong term production test in order to determine the fault compartment volume, to\r\ndetermine the threshold pressures and degree of communication through faults, to\r\nestablish the intervals contributing to the flow, to determine reservoir\r\nproductivity and initial reservoir conditions, and to obtain representative\r\nfluid samples.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 6407/7-2 was re-entered with the semi-submersible\r\ninstallation Vildkat Explorer on 7 March 1990. \u003c/p\u003e\r\n\r\n\u003cp\u003eTwo test strings were run sequentially.\r\nThe first string was a test string to enable a conventional well test to be\r\nconducted. Most of the upper part of this test string was later pulled and\r\nreplaced by an abandonment string with gauges to allow long term monitoring of\r\nthe main build up.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe gauges were programmed to record data\r\nover a period of 4 to 6 months. The well was subsequently abandoned for later re-entry\r\nand retrieval of the gauges and permanent abandonment.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eA conventional long-term production test\r\nwas carried out from the combined intervals 2773.3 - 2778.3 m, 2781.3 - 2797.8\r\nm, 2803.8 - 2839.3 m, and 2844.3 - 2879.3 m. In the main flow the test produced\r\n853 Sm3 oil and 173650 Sm3 gas through a 20.64 mm choke. The GOR was 203\r\nSm3/Sm3, the oil density was 0.800 g /cm3, and the gas gravity was 0.714 (air =\r\n1). The maximum down hole temperature in the test was 113.3 deg C, recorded at\r\nthe PLT at 2754.4 m. This is estimated to be the initial reservoir temperature\r\nat mid-perforations, 2826.3 m.\u003c/p\u003e\r\n\r\n\u003cp\u003e \u003c/p\u003e\r\n\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"693","properties":{"OBJECTID":693,"wlbNpdidWellbore":1514,"wlbName":"30/9-10","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 30/9-10 was drilled in the Omega\r\nSouth segment on the Oseberg Fault Block in the North Sea. The primary\r\nobjective was to test the hydrocarbon potential in the Tarbert Formation.\r\nSecondary objectives were to test the Cook Formation and the Statfjord Group.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well was spudded with the\r\nsemi-submersible installation Vildkat on 31 July 1990 and drilled to TD at 3649\r\nm in the Early Jurassic Statfjord Group. An 8 1/2" pilot hole was drilled\r\nfrom 210 to 350 m to check a possible shallow gas zone at 329 m. No gas was\r\nencountered. No significant problem was encountered in the operations. The well\r\nwas drilled with spud mud down to 1059 m and with KCl/polymer mud from 1059 m\r\nto TD. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe Draupne Formation was encountered at\r\n2717 m and Intra Draupne Formation sandstone was penetrated from 2756 m to top\r\nTarbert Formation at 2783 m. The Draupne Formation sandstone and the Upper\r\nTarbert Formation were found to be oil bearing from 2756 - 2833 m. Poor to\r\nmoderate oil shows continued down to 2858 m. No oil shows were recorded below\r\nthis depth or above top Draupne Formation. The Middle Tarbert is poor or tight,\r\nand non-moveable hydrocarbons were present in the Lower Tarbert, which are\r\ninterpreted from core analysis to be residual oil. The net pay was determined\r\nto be 55 m, with an average water saturation of 36.4% and average porosity of\r\n17.5%. RFT data defines an oil gradient through Draupne and Upper Tarbert\r\nsandstones, which intersects with the Lower Tarbert water gradient at 2833 m in\r\nthe Middle Tarbert. However, it is uncertain whether the oil gradient in the\r\nUpper Tarbert and the water gradient of the Lower Tarbert belong to the same\r\npressure system. Consequently an oil-water contact was not proven in","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"694","properties":{"OBJECTID":694,"wlbNpdidWellbore":1520,"wlbName":"6507/6-2","wlbHistory":"\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 6507/6-2 was drilled in the north-western\r\ncorner of the block on a rotated fault block on the Dønna Terrace, immediately\r\nnorthwest of the main fault zone separating the Dønna Terrace from the Nordland\r\nRidge. The main objective of the well 6507/6-2 was to test the hydrocarbon\r\npotential in the Fangst Group and in the Tilje Formation. A secondary target\r\nwas to test the reservoir properties and hydrocarbon potential of a Cretaceous dome\r\nshaped structure interpreted to be a potential Lysing Formation Equivalent. The\r\nsource rock properties in the Spekk and Åre Formations would be tested by the\r\nwell. The commitment was to drill at least 50 m into rocks of Triassic age;\r\nwith planned TD at 4200 m. No shallow gas warnings were given for this well.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 6507/6-2 was spudded with\r\nthe semi-submersible installation West Alpha on 27 April 1991and drilled to TD\r\nat 4345 m (4343 m TVD RKB) in Late Triassic sediments of the Åre Formation. Only\r\nminor problems occurred while drilling. The well was drilled with spud mud down\r\nto 1040 m, with KCl mud from 1040 m to 3413 m, and with Hi-Temp polymer mud\r\nfrom 3413 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well mainly penetrated claystones\r\nwith minor silt and sandstone intervals down to Top Cromer Knoll Group at 2663\r\nm. In the Cromer Knoll Group the lithology was mainly claystone with thin\r\nintervals of sandstone and limestone. The reservoir in the Fangst Group was\r\nreached at 3727 m, 336 m deeper than prognosed and proved to be dry. However,\r\noil was found in a thin sand bed in the Lange Formation (Turonian age) at 2754\r\n- 2757 m. This sand was neither cored nor production tested, but oil was\r\nrecovered by RFT sampling. \u003c/p\u003e\r\n\r\n\u003cp\u003eSporadic shows were recorded in thin\r\nsandstone stringers at several levels in the Lange Formation (2745 to 2753 m, 2885\r\nm, 2945 - 2955 m, and 2946 m). The well encountered a 102 m thick Spekk\r\nFormation sequence at 3174 m. The Spekk Formation had excellent ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"695","properties":{"OBJECTID":695,"wlbNpdidWellbore":1521,"wlbName":"1/3-6","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 1/3-6 is located between the Gyda,\r\nUla, and Blane fields in the Central Graben of the Norwegian North Sea.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe primary objective was Late Jurassic\r\nUla sands deposited as a rim syncline linked to salt diapirism. The Ula sands had\r\nbeen found hydrocarbon bearing in several wells in the surrounding blocks. Secondary\r\nobjective was Late Paleocene "Cod sands" (Forties Formation), which could\r\nbe present in the 1/3-6 area and could pinch out towards the diapir. The prognosed\r\nTD was 5030 m below MSL. The "Cod sands" were considered a\r\nlow-probability target.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 1/3-6 was spudded with the\r\nsemi-submersible installation Dyvi Stena on 11 March 1991. Drilling performance went on without significant problems but the primary target of the well was\r\nnot reached. The discovery of a significant hydrocarbon-bearing reservoir in\r\nthe Paleocene activated the contingency measures of the programme (to set an\r\nextra 11 3/4" liner). For safety and technical reasons, and to allow for a\r\nproper test of the Paleocene, the well was stopped at 3586 m in the Late\r\nCretaceous Hod Formation. No shallow gas was encountered while drilling. The\r\nwell was drilled with a KCl polymer mud.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well encountered 85 m of hydrocarbon\r\nbearing Forties sands at 2913.5 m. The pay zone was 44 m thick with a\r\nhydrocarbon saturation of 56 %. No hydrocarbon-water contact was found. Apart\r\nfrom the hydrocarbons in the Forties sands oil shows were also recorded from\r\n3519 to 3530 m in the Tor Formation.\u003c/p\u003e\r\n\r\n\u003cp\u003eOne conventional core was cut at 2921 m\r\nto 2928.5 m in the Forties sands. Segregated fluid samples were taken at three\r\ndepths: 2923 m (filtrate and gas), 2937 m (filtrate and gas), and two samples\r\nat 2973.5 m (filtrate and gas in one and filtrate only in the other).\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 22 June 1991 as a gas-condensate discovery.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThree DST tests were p","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"696","properties":{"OBJECTID":696,"wlbNpdidWellbore":1523,"wlbName":"35/11-4","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 35/11-4 was designed to drill at a\r\nsite located in block 35/11 which is situated on the eastern flank of the\r\nViking Graben and northwest of the Horda Platform. The regional structural\r\ngenerally trends north-south, with some north-northeast components. Planned TD\r\nwas 3317 m, which was prognosed to be near top Triassic. The primary objective\r\nfor 35/11-4 was the Middle Jurassic Brent Group. Reservoirs were expected in\r\nthe Tarbert, Ness, Etive and Oseberg formations. Secondary targets were\r\npossible sand development of Sognefjord Formation sand in the Late Jurassic as\r\nwell as Paleocene sand mounds.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 35/11-4 was spudded with the\r\ndynamically positioned semi-submersible installation Yatzy on 18 August 1990\r\nand drilled to TD at 3127 m in the Early Jurassic Statfjord Formation. Yatzy\r\nwas the first dynamically positioned drilling unit used offshore Norway and\r\n35/11-4 was the rig's first well. This implied significant rig time spent on\r\ntesting and down time due to failure of first-time equipment. At a depth of\r\n2072 m one decided to sidetrack the well from 1700 m in order obtain cores from\r\nthe hydrocarbon bearing zones of the Sognefjord formation. This led to a\r\nmaximum deviation of 5.7 deg at 1765 m. The well was drilled with seawater and\r\nviscous pills down to 1009 m and with KCl/polymer mud from 1009 m to TD. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe Lower Eocene consisted of a\r\ncontinuous argillaceous sequence and no reservoir rocks were penetrated. At\r\n1647 m good reservoir quality sandstones were found in the Paleocene Lista\r\nFormation but they were not hydrocarbon bearing. Poor shows were observed in\r\nlimestones of the Cretaceous Shetland Group. A total of four\r\nhydrocarbon-bearing zones were discovered in the Jurassic: in the Sognefjord\r\nFormation in the original hole and in the Sognefjord, Fensfjord Formations and\r\nBrent Group in the sidetrack hole. Mud log shows were recorded in most of the\r\nsandstone intervals from 1984 meters to","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"697","properties":{"OBJECTID":697,"wlbNpdidWellbore":1524,"wlbName":"15/12-6 S","wlbHistory":"\r\n\r\n\u003cp\u003eBlock 15/12 is situated between the Jæren\r\nHigh to the south, Central Graben to the south-southwest, Andrew Ridge to the\r\nwest, Ling Graben to the north and Viking Graben to the north-northwest. Well\r\n15/12-6 S was the third well within the license area. It was drilled ca 3 km\r\nnorth of the 15/12-4 Varg Discovery well, which found 1.5 oil column in\r\nJurassic sandstone. The main objective of 15/12-6 S was to test the hydrocarbon\r\npotential in Oxfordian sandstone in the north-western segment of the Beta west\r\nstructure. Secondary objectives were Palaeocene sandstones (Maureen formation)\r\nand Triassic sandstones. Due to possible shallow gas problems, the well was\r\nmoved 100 south to avoid this problem.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 15/12-6 S was spudded 19 August 1990\r\nwith the semi-submersible rig Deepsea Bergen and drilled to 3050 m in the\r\nTriassic Skagerrak Formation. While drilling the 12 1/4" hole the penetration\r\nstopped at 2560 m. The BHA was pulled out and it was found that the MWD tool had\r\nbeen twisted off. The hole was cemented back and sidetracked from 2495 m with\r\nincreased mud weight. Ran 7" liner to 3046 m, and cemented inside the\r\nliner to 2960 m. No shallow gas was encountered. The well was drilled with\r\nbentonite spud mud and CMC/seawater down to 615 m, with gypsum/polymer mud from\r\n615 m to 2757 m, and with gel/lignosulphonate mud from 2757 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eLogs and shows indicated presence of\r\nhydrocarbons in the interval from 2428 to 2473 m in the late Cretaceous chalk\r\nbut tests were not performed here due to tight formation. The Late Jurassic\r\nOxfordian sandstone (Hugin Formation) came in at 2871 m, 80.5 m deeper than\r\nprognosed. It contained oil and from logs the OWC was found to be at 2943 m.\r\nThere were no shows or other hydrocarbon indications below this depth.\u003c/p\u003e\r\n\r\n\u003cp\u003eA total of seven cores were cut, six in\r\nthe interval 2838 to 2966 m and the seventh from 2980 to 2988.5 m. An FMT run\r\nin Oxfordian sandstone gave 12 pressure readings out of 2","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"698","properties":{"OBJECTID":698,"wlbNpdidWellbore":1527,"wlbName":"2/6-4 S","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 2/6-4 S is located in the northwest\r\npart of the Søgne Basin in the North Sea. It was drilled on the flank of a salt\r\ndome. The objectives were to evaluate the potential of the Late and Middle\r\nJurassic series, which were supposed to accommodate three reservoirs; turbiditic\r\nsands in the Mandal-Farsund Formations, shallow marine Ula Formation sands of\r\nKimmeridgian to Volgian age, and fluvial sands of the Middle Jurassic. Oil was\r\nexpected with only small amounts of associated gas. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 2/6-4 S was spudded with the\r\nsemi-submersible installation West Vanguard on 8 April 1990 and drilled to TD\r\nat 3627 m (3617 m drillers depth, 3584 m TVD MSL drillers depth) in the Late\r\nPermian Zechstein Group. The well was drilled deviated down to 2330 m to avoid possible\r\nshallow gas pockets seen on seismic. No shallow gas was encountered. From 2330\r\nm it was drilled with an average of 15 deg dip to the target at 3402 m, then\r\ndropping of to less than 10 deg dip for the rest of the well down to TD. No\r\nsignificant drilling problems occurred during drilling operations, but due to a\r\nproblem of tie-in with gamma ray drillers depth was 10 m shallower than logger's\r\ndepth in the lower part of the well. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe results of the well were\r\ndisappointing since the Ula formation was missing, and only two meters of\r\nKimmeridgian sands were encountered at 3537 m (3527 m driller's depth). These\r\nsands were very glauconitic, silty and well cemented with porosity estimated\r\naround 5-7%. The Bryne formation was thicker than expected, but had limited\r\nreservoir quality with only some thin sand beds separated by shaley layers\r\ntowards the base of the Formation. All Jurassic sands were water bearing\r\nwithout shows, except for some fluorescence in fissures in a coal at the top of\r\nthe Bryne Formation. Small shows at 2930 to 3040 m (in upper Tor Formation) were\r\ndescribed as: "- background gas increases and remains between 1 to 7.7 %\r\n(max at","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"699","properties":{"OBJECTID":699,"wlbNpdidWellbore":1530,"wlbName":"34/10-33 CR","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 34/10-33 CR was the last in a\r\ncluster well bores drilled to appraise the Gullfaks South discovery beginning\r\nwith well 34/10-33. Well 34/10-33 CR is the re-entry of well 34/10-33 C, which\r\nserved as a host well for the long-term production test 34/10-T-33 C. \u00A0In this\r\ntest the production logging tools failed and the bottom hole pressure recorders\r\nwere only partly functioning in the long-term production test. Furthermore, an\r\nunexpected increase in GOR occurred during the test, and this could not be\r\ninterpreted based on the available data. Therefore the programme for the\r\nre-entry included a new test from the same perforation interval. A further objective\r\nof the re-entry was to retrieve and read two pressure recorders that were left\r\nin the well 34/10-33 C after the test production. The mean reservoir pressure\r\nshould be estimated from these data. After testing the well bore would be\r\npermanently abandoned.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 34/10-33C was re-entered\r\nwith the semi-submersible installation Deepsea Bergen on 24 February 1990. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe pressure recorders were retrieved,\r\nbut both had failed to work.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo cores were cut and no wire line fluid\r\nsamples were taken.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAfter testing the well was permanently\r\nabandoned on 27 April 1990 as an oil and gas appraisal well.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eTesting\u003c/span\u003e\u003c/b\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThree drill stem tests were attempted\r\nfrom perforations in the interval 3448 to 3517 m (3347.3 to 3395.4 m TVD MSL).\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eDST 1 was not initiated due to technical\r\nreasons.\u003c/span\u003e","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"700","properties":{"OBJECTID":700,"wlbNpdidWellbore":1533,"wlbName":"6507/3-1","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 6507/3-1 is located west-southwest\r\nof the Norne Field on the Dønna Terrace offshore Mid Norway. The prospect,\r\ncalled the Alpha structure, was defined as a horst structure oriented in a\r\nnortheast - southwest direction on the Dønna Terrace, west of the Nordland\r\nRidge in the northern part of the block. The northern part of the structure\r\nextended into block 6607/12. The well was expected to penetrate rocks of\r\nCenozoic-, Cretaceous-, and Jurassic age. The primary objective of the well was\r\nto test the hydrocarbon potential of the Middle to Early Jurassic Fangst and Båt\r\nGroups. Secondary objectives were to test possible reservoirs in the Early\r\nCretaceous (Cromer Knoll Group) and Late Jurassic (Rogn Formation sands). The\r\ncommitment of the well was to drill into rocks of Triassic age or to 5000 m.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 6507/3-1 was spudded with\r\nthe semi-submersible installation Ross Rig on 12 May 1990, and drilled to TD at 4757 m in Late Triassic sediments of the Åre Formation. After having set the\r\n9 5/8" casing with shoe at 3167 m, an 8 1/2" hole was drilled to 4080\r\nm. This hole, especially the Melke Formation, became very unstable and caused\r\nserious drilling problems. After having worked with stuck pipe and fish, the\r\nhole was finally plugged back to the 9 5/8" casing shoe and sidetracked from\r\n3177 m, (a technical bypass) and drilled to TD. Due to the problems encountered\r\nthe first hole was logged from 3850 m to hole TD at 4080 with MWD only, while\r\nthe sidetracked hole was not logged below 4506 m. The Directional survey shows\r\na practically vertical well with TVD only one meter short of MD down to this\r\ndepth. The well was drilled with seawater and CMC hi-vis pills down to 900 m,\r\nwith gypsum/polymer mud from 900 m to 3183 m, with gel/lignosulphonate mud from\r\n3183 m to 3974 m, and with Kemseal/PAC/Miltemp mud from 3974 m to final TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eTop of the Garn formation was penetrated\r\nat 3608 m. Above this level no","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"701","properties":{"OBJECTID":701,"wlbNpdidWellbore":1534,"wlbName":"25/1-7 R4","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 25/1-7 was drilled on the main Frigg\r\nstructure close to the UK border. The Frigg Field was discovered by well 25/1-1\r\nin 1971. Production from the field started in 1977. A main objective of well\r\n25/1-7 was to establish a reference monitoring station for the production of\r\ngas from the Frigg Field. The 25/1-7 R4 was the fourth and last re-entry of the\r\nwell.The purpose was to log the fluid contacts, and to perform permanent\r\nplugging and abandonment. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 25/1-7 R4 was connected\r\nand re-entered with the semi-submersible installation West Vanguard on 28 March\r\n1990.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was logged (2054.5 - 1913 m) through\r\ncasing with a Thermal Neutron Decay (TDT) log to determine the fluid contacts. The\r\ngas/water contact was found at 1912.2 m MSL, an 8.0 m rise of the water level\r\nsince April 1989, and a 35.8 m total rise compared to the Frigg pre-production\r\ngas/oil contact in the area. A cased hole RFT run was also performed, and the\r\npressure was measured at 1897.2 m, 1919.2 m, 1932.2 m, and at 1961.2 m.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was permanently abandoned on 5\r\nApril 1990 as a gas appraisal well. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eTesting\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo drill stem test was performed.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"702","properties":{"OBJECTID":702,"wlbNpdidWellbore":1536,"wlbName":"34/7-17 A","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 34/7-17 A is a sidetrack to well\r\n34/7-17 on the Vigdis Field on Tampen Spur in the Northern North Sea. In well\r\n34/7-17 the primary target Brent reservoir was encountered 38 m deeper than\r\nprognosed and dry with only scattered oil shows. The 34/7-17 A sidetracked well\r\nthus aimed primarily at the Brent reservoir in an up-dip position above a\r\npossible OWC. According to prognosis Brent should be truncated in this\r\ndirection. A secondary objective was to test the pressure regimes in the\r\nJurassic sequence, including possible depletion associated with pressure\r\ncommunication, previously identified in the nearby Tordis Field.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 34/7-17 A was spudded with the semi-submersible\r\ninstallation Treasure Saga on 7 April 1991. Kick off point was at 1994 m below\r\nthe 13 3/8? casing shoe in well 34/7-17, in the top of the Shetland Group. The\r\ntarget was located up-dip in a south-easterly direction and the sidetrack was\r\ndrilled deviated from its beginning. The well was drilled without significant\r\ntechnical problems to TD at 2650 m (2557 m TVD) in the Middle Jurassic Etive\r\nFormation of the Brent Group. It was drilled with KCl mud from kick off to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eTop Brent Group, Tarbert Formation, was\r\npenetrated at 2494.5 m (2439.5 m TVD). Truncation was confirmed by the absence\r\nof the Viking Group and erosion into the top of the Brent Group. The Brent\r\nGroup proved to be oil bearing only in the uppermost 6.5 m TVD with a possible\r\nOWC at 2502.5 m (2446 m TVD / 2420 m MSL TVD). Above the reservoir ditch\r\ncuttings recorded a continuous sequence with good traces of oil shows between\r\n2235 and Top Brent Group. The interval 2310 to 2370 m also had oil staining and\r\na strong odour of hydrocarbons. No shows were reported below 2506 m.\u003c/p\u003e\r\n\r\n\u003cp\u003eOne core was cut in the top of the\r\nreservoir between 2597 and 2617. Totally 21 m was cut, of which 20 m was\r\nrecovered.\u003c/p\u003e\r\n\r\n\u003cp\u003eTwo RFT runs were conducted over the\r\nBrent Group. The resulting pressure ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"703","properties":{"OBJECTID":703,"wlbNpdidWellbore":1539,"wlbName":"6406/11-1 S","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well 6406/11-lS was drilled on a\r\ntruncational/fault seal trap structure on the western slope of the Frøya High\r\nnear the southern end of the Halten Terrace. The main objective of the well was\r\nto test the hydrocarbon potential in the Early to Middle Jurassic Fangst Group.\r\nSecondary objectives were to test the reservoir properties the underlying Tilje\r\nFormation, as well as possible sand development in the Tertiary. The well\r\nshould also evaluate the source rock properties in the Early Jurassic Åre\r\nFormation. Planned total depth was 4526 m RKB TVD beneath a seismic marker\r\ninterpreted as Triassic Evaporite. The well was the first well on a new block\r\nand the pressure prognosis was uncertain. Formation pressures were to be\r\nwatched closely while drilling.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 6406/11-1 S was spudded with\r\nthe semi-submersible installation Treasure Saga on 19 October 1990 and drilled\r\nto TD at 4185 m in the Late Triassic Red Beds. To avoid shallow gas the well\r\nwas spudded and drilled deviated from a location 260 m NNW of the planned\r\ntarget location. During drilling the Nordland Group, two shallow gas intervals\r\nwere penetrated at 893 - 897.5 m and 1148 - 1150 m. To get back to vertical\r\ndrilling the well was deviated from 1235 m to 2165 m MD. Only minor problems\r\noccurred while drilling down to the 12 1/4" section. After drilling the 12\r\n1/4" hole down to 3395 m, the VSP tool become stuck at 3383 m. A total of\r\n5 days were spent recovering the wire line and miring the fish down. Only minor\r\nproblems with tight spots occurred while drilling to TD. \u003c/p\u003e\r\n\r\n\u003cp\u003eFormation pressure was hydrostatic down\r\nto ca 1520 m, from where a gradual pressure build up was indicated in the\r\nHordaland Group down through the Rogaland Group, estimated to a maximum of 1.60\r\ng/cc EMW at 2400 m in the upper part of the Shetland Group. From here a slight\r\npressure depletion down to approximately 3000 m was indicated. From 3000 m down\r\nto the Jurassic ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"704","properties":{"OBJECTID":704,"wlbNpdidWellbore":1544,"wlbName":"34/7-15 S","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 34/7-15 S was the first well drilled\r\non the east flank of the 34/7 block. This part of the block has mainly been\r\nsubsiding during Late Jurassic, Early and Late Cretaceous on the Tampen high\r\nand hence not been exposed so heavily to the erosive events, whereas the\r\nstructures elsewhere in the block have suffered periods of erosion and\r\nnon-deposition. The westward tilting of the Tampen area developed in these\r\nperiods, and a large part of the erosion products were deposited to the west.\r\nThe eastern flank received coarse clastic sediments, developed as fans next to\r\nthe Inner Snorre Fault. The Middle Jurassic Brent Group probably shows the same\r\ndevelopment as elsewhere in the Tampen area. Seismic anomalies indicate\r\npossibilities for shallow gas. The primary objectives of well 34/7-15 S were to\r\ntest the prospectivity of the Brent Group, and thereby test the sealing\r\ncapacity of the Inner Snorre Fault; to test the stratigraphy and prospectivity\r\nof the Early Cretaceous and Late Jurassic sediments; and to obtain better\r\nseismic and velocity control of the Cretaceous and Jurassic sediments. The well\r\nfulfilled the work commitment of PL 089.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 34/7-15 S was spudded with\r\nthe semi-submersible rig Treasure Saga 23 May 1990 and drilled to TD at 4646 m\r\nin the Early Jurassic Drake Formation. The well was drilled as a deviated well\r\nto the east with kick-off point at 2900 m. It was drilled with seawater and gel\r\ndown to 1038 m and with KCl mud from 1038 m to TD. No shallow gas was\r\nencountered. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe sandstones of the Brent Group\r\n(Tarbert Formation) came in at 4376 m. Oil shows were recorded in thin Intra\r\nDraupne and Intra Heather Sandstones. The Brent Group proved to be water\r\nbearing with some insignificant oil shows. A total of 250 sidewall cores were\r\nattempted and 151 cores were recovered. One core was cut in the Tarbert\r\nFormation from 4379 m to 4394 m. One FMT segregated sample was taken at 3599.5\r\nm in o","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"705","properties":{"OBJECTID":705,"wlbNpdidWellbore":1545,"wlbName":"30/6-23","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 30/6-23 was drilled on the Beta\r\nSouth structure on the Brage Horst and south of the Veslefrikk Field in the\r\nNorth Sea. The Beta structure is surrounded by producing oil fields or\r\ncommercial discoveries. On Beta, oil has been discovered in the Middle Jurassic\r\nBrent Group reservoirs in fault-block traps. The oil is contained in two main\r\nsub-structures, i.e. the Beta Saddle and Beta South, comprising several smaller\r\nsub-compartments. The discovery well on Beta was the 30/6-5 well, but this well\r\nwas not tested due to the detection of H2S in the RFT samples. Later wells\r\nproved oil in the Beta Saddle without encountering H2S. The Beta Saddle is\r\ncharacterized by a multicontact reservoir having prominent shale barriers.\r\nThere are also slight differences in fluid composition between the two\r\ncompartments, which suggests that the saddle through is acting as a structural spill\r\npoint at the top Etive level. Primary target for the well was Base Brent Group\r\nprognosed to come in at 2891 m. Secondary objective was top Statfjord prognosed\r\nat 3141 m. OWC was expected at 2880 m.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 30/6-23 was spudded 29\r\nApril 1990 by the semi-submersible rig Transocean 8 and drilled to TD at 3209.5\r\nm in the Early Jurassic Eirikson Formation. Shallow gas was indicated from mud\r\ngas and MWD at several levels between 440 m and 603 m. Gas influx occurred\r\nduring a wiper trip back from 601 m to the 30" casing shoe at 261 m. Otherwise\r\ndrilling proceeded without any significant issues. The well was drilled with\r\nspud mud down to 378 m and with KCl/polymer mud from 378 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eFormation tops came in approximately as\r\nprognosed. Top Viking Group was encountered 2534 m and consisted of 82 m\r\nDraupne Formation and 177 m Heather Fo","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"706","properties":{"OBJECTID":706,"wlbNpdidWellbore":1547,"wlbName":"2/7-23 S","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 2/7-23 S was the fourth well drilled\r\non the South Eldfisk (Embla) Field, which consists of a faulted structural high\r\nof assumed Palaeozoic sediments and volcanics. The structure is located on the\r\neastern boundary of the Grensen Nose, a prominent faulted terrace marking the\r\nwestern edge of the Central Graben. The purpose of the well was to test the\r\nnorthward extension of the hydrocarbon bearing sandstones discovered in the\r\n2/7-9 well in 1974 and confirmed by tests in the 2/7-20 and 2/7-21 S wells. If\r\nreservoir was proven, the intent was to complete the well in a manner suitable\r\nfor a later tie-back to a production facility, where it would provide a third\r\ndrainage point for future field development of the Embla Field. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eAppraisal well 2/7-23 S was spudded with\r\nthe semi-submersible installation West Delta on 15 May 1990 and drilled to TD\r\nat 4760 m in indeterminate pre-Jurassic sandstone. The well was drilled from\r\nthe third slot in a three-slot temporary template located over the 2/7-20 well.\r\nThe 2/7-23 S well was deviated to a target location at the Base Cretaceous\r\nlevel 1227 m north of the wellhead. Shallow gas was encountered at 593 m and\r\ncaused some operational problems. The drilling went on without significant\r\nproblems to TD, but during preparations for testing the drill string got stuck.\r\nAttempts to work the pipe free met with no success and the pipe had to be cut.\r\nThe remainder of the drill string could not be retrieved and it was decided to\r\nabandon the well without testing. The well was drilled using KCL/Soltex/Aktaflo-S\r\nwater based drilling fluid down to the 9 5/8" casing depth at 4229 m.\r\nBelow this point and for the remainder of the well Enviromul oil based mud was\r\nused.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well penetrated 4 m of Late Jurassic\r\nshale (Mandal Formation) at 4408 m. The target pre-Jurassic reservoir sands\r\nwere encountered at 4412 m, 74 m TVD deeper than prognosed. The reservoir was\r\noil-bearing. No disti","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"707","properties":{"OBJECTID":707,"wlbNpdidWellbore":1548,"wlbName":"2/4-14 R2","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 2/4-14 R was designed to\r\nre-establish full well control of the uncontrolled flow in well 2/4-14 by using\r\nboth well 2/4-14 R and 2/4-15 S. Well 2/4-14 R2 is a result of the final\r\ncompletion of the blow out.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThe re-entry 2/4-14 R2 was performed with\r\nthe semi-submersible installation Treasure Saga. Operations started on 6 April\r\n1990, after the jack up installation Neddrill Trigon had suspended the hole and\r\nleft location. Riser and LMRP was run and cement was drilled inside the 13\r\n3/8" casing. The casing was cut at 169 m, the hole cleaned and a Baker PIP\r\npacker was set at 165 m in a second attempt. A leak in the 20" casing was\r\nobserved between the wellhead and the packer. A balanced cement plug was set\r\nfrom 158 to 133 m. The 20" and 30" casings were cut at 99.5 m. A\r\nchannel through the cement between 20" and 30" casing was observed. A\r\ncement plug was set from 99 m to the seafloor.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well bore was permanently abandoned\r\non 14 April 1990 as a junked well.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was performed.\u003c/p\u003e\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"708","properties":{"OBJECTID":708,"wlbNpdidWellbore":1549,"wlbName":"6201/11-2","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 6201/11-2 was designed to drill the\r\nOksen prospect in the southwestern corner of block 6201/11. A prominent NE-SW\r\ntrending ridge complex occupies the southern part of this block, separating the\r\n Møre Basin from the northern North Sea along the Møre Trøndelag fault complex.\r\nThe reservoir rocks of the Oksen prospect were interpreted as synrift submarine\r\nfan deposits of Kimmeridge age located in a half graben between two Triassic\r\nHighs. Trapping mechanism were stratigraphically dependant on sealing faults\r\ntowards rotated Triassic rocks in southeast. The objectives of the well were to\r\ntest the hydrocarbon and reservoir potential of the Late Jurassic play-concept\r\n(Magnus Sand) and to test the geophysical and structural interpretation of the\r\narea and give valuable information on palaeontology and geochemistry.\u003c/p\u003e\r\n\r\n\u003cp\u003eShallow gas warnings were given for two\r\nlevels.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 6201/11-02 was spudded with\r\nthe semi-submersible rig Deepsea Bergen on 8 January 1991 and drilled to TD at\r\na total depth of 3778 m in the Jurassic Heather Formation. The well was drilled\r\nwith seawater/CMC/viscous plugs down to 780 m, with KCl/polymer mud from 780 m\r\nto 3335 m, and with gel/lignosulfonate mud from 3335 m to TD. The well was\r\ndrilled without major problems, except for 3 days lost rig-time due to low\r\nleak-off value at the 20" casing shoe.\u003c/p\u003e\r\n\r\n\u003cp\u003eTop Late Jurassic was encountered at 3339\r\nm, which is 24 m lower than prognosed. No potential reservoir rocks were\r\nencountered in the Late/Middle Jurassic. The biostratigraphic breakdown was\r\ndifficult to interpret from approximately 3650 m and to TD with Triassic shale\r\noverlying the Late Jurassic Heather Formation towards TD. It is thus possible\r\nthat the Jurassic and Triassic sequences in this well represent slumped/slided\r\nsediment packages similar to the situation in well 33/5-2 not very far to the\r\nsouth. The only shows recorded were cut fluorescence in claystones in the\r\nin","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"709","properties":{"OBJECTID":709,"wlbNpdidWellbore":1550,"wlbName":"34/7-16","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 34/7-16 is located between the\r\nStatfjord and Snorre Fields on Tampen Spur in the Northern North Sea. The\r\nprimary purpose of the well was to test the Brent Group reservoir on the C-Plus\r\nprospect. A secondary objective was to test the reservoir of the Statfjord\r\nFormation. The well was drilled on a high position of the structure and was\r\nestimated to reach the reservoir at 2349 m MSL. Shallow gas could occur at 448,\r\n500, and 557 m.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 34/7-16 was spudded with the\r\nsemi-submersible installation Scarabeo 5 on 13 August 1990 and drilled to TD at 2700 m in the Early Jurassic Amundsen formation. At this depth the well\r\nwas temporary abandoned due to time schedule for the rig. No significant\r\nproblems were encountered in the operations. The resistivity log indicated\r\nsmall amounts of gas in a sand layer at 447 m. Otherwise no indication of\r\nshallow gas was observed. The well was drilled with spud mud down to 922 m and\r\nwith KCl mud from 922 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eApart from the sandy Utsira Formation of\r\nMiocene/Pliocene age encountered between 976 - 1081 m the well penetrated\r\nmainly clay stone down to the Top Jurassic. Late Cretaceous (Coniacian age)\r\nsediments were found to rest unconformable on the Middle Jurassic Brent Group reservoir\r\nat 2390 m. The reservoir was hydrocarbon bearing. From the log, pressure\r\ngradient analyses, and FMT sampling the OWC was found at 2487 m, in the Rannoch\r\nFormation. Shows were recorded from 2 m above and to 2 m below the oil-bearing\r\nreservoir. Weak shows were also observed in the upper part of the Cook\r\nFormation.\u003c/p\u003e\r\n\r\n\u003cp\u003eEight cores were cut in the well. One\r\ncore was cut in the Shetland Group, from 1935 to 1953 m, for borehole stability\r\nstudies. Seven cores were cut in the Brent Group and into the Dunlin Group (8.0\r\nm), in the interval 2389 - 2522 m (driller's depth). The Brent core recovery\r\nwas 130.8 m, i.e. 98%. \u003c/p\u003e\r\n\r\n\u003cp\u003eFour FMT segregated samples were taken in\r\nthe Brent Group re","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"710","properties":{"OBJECTID":710,"wlbNpdidWellbore":1551,"wlbName":"6306/10-1","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 6306/10-1 was designed to drill the\r\nSkalmen prospect, a structural closure located at the northern apex of the\r\nGossa High in block 6306/10. Amplitude anomalies was seen at 280-, 300-, 400-,\r\n1200 to 1300-, and 2200- 2400 ms. The primary objective of the well was to test\r\nthe hydrocarbon potential of Early Jurassic and Pre-Jurassic sequences,\r\nbelieved to be developed in a sandy facies of deltaic/fluvial origin. Secondary\r\nobjective was to test potential reservoir developments in the Cretaceous and\r\nthe Late Jurassic within dip-closure. A third objective was to test the\r\nhydrocarbon potential of Paleocene sands. The well should be drilled some\r\n250-300 m into rocks of Pre-Jurassic age and would penetrate the primary\r\nobjective some 300 m down-dip from the structural culmination. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 6306/10-1 was spudded with\r\nthe semi-submersible installation Dyvi Stena on 7 September 1990 and drilled to\r\nTD at 3187 m in basement rocks. Shallow gas was not observed. Overcompacted\r\nsediments and boulders caused some problems, and the well had to be re-spudded\r\nseveral times. Bad weather caused some delay in the drilling procedure, as the\r\nstring was temporary hung off several times. The well was drilled with\r\nBentonite and seawater down to 610 m and with PAC/gypsum mud from 610m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well encountered close to 150 m of\r\nPaleocene Egga sand at 1138 m. Some sand developments were seen also in an\r\nIntra-Kvitnos Unit at 1825 m and in a 7 m thick Lysing Formation at 1992 m. The\r\nwell penetrated a hiatus from Aptian to Early Callovian at 2692 m. The Middle\r\nJurassic section from 2692 m to 2980 m contained about 60 m net sand with\r\nrelatively low porosities and poor permeabilities, based on petrophysical log\r\nevaluation. The logs also showed that this section was gas bearing. Shows were\r\nrecorded in the Egga Informal unit from 1142 m to 1180 m, in sandstone\r\nstringers in the interval 1992 m to 2470 m in the Lysing and Lange F","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"711","properties":{"OBJECTID":711,"wlbNpdidWellbore":1552,"wlbName":"2/8-14","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 2/8-14 was drilled on a complexly\r\nfaulted anticline situated below the western flank of the Valhall Field\r\n(designated as the West Valhall prospect) in the southern North Sea. The\r\nprimary objective was to test a late Jurassic "wedge" sandstone. The\r\nsecondary objective was Late Jurassic, Volgian age, sandstones. The well would\r\nalso determine reservoir quality of the Shetland Group chalk sequences. The\r\nplanned total depth of the well was 5622 m.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 2/8-14 was spudded with the\r\nsemi-submersible installation West Vanguard on 14 August 1990. No shallow gas\r\nzones were penetrated in the well. The well penetrated high pore pressures at\r\n3176 m in the Lower Cretaceous that required plugging back the well and setting\r\nan 11 3/4" liner. High pore pressures were again penetrated at 4274 m in\r\nthe Late Jurassic. Due to well control considerations, the hole was plugged\r\nback and sidetracked below approximately 3797 m before setting a 7" liner\r\nat 4202 m. Further down high pore pressures again forced a premature end to the\r\nwell with TD at 4397 m in the Late Jurassic (Late Kimmeridgian) Farsund\r\nFormation. The well was drilled with seawater and pre-hydrated bentonite down\r\nto 952 m, with KCl/PHPA/Polydrill mud from 952 m to 2560 m, with AncoTemp\r\nPolydrill/Ancoresin PHPA from 2560 m to 3855 m, and with AncoTemp\r\nPolydrill/Hostadrill PHPA mud from 3855 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eTop Shetland Group Chalk (Tor Formation)\r\nwas encountered at 2614 m with a 73% mud gas peak and good oil shows. The Tor\r\nFormation was 3 m thick and the underlying Hod Formation was 225 m thick. The\r\npressures in the Tor and in the Hod chalk formations were depleted due to\r\nproduction from the Valhall Field as expected. Top Tyne Group, Mandal","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"712","properties":{"OBJECTID":712,"wlbNpdidWellbore":1557,"wlbName":"7/12-10","wlbHistory":"\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 7/12-10 was drilled a few km north\r\nof the Ula Field, on the north-eastern side of the Cod Terrace in the North\r\nSea. The primary objective was to prove a commercial volume of oil in the Late\r\nJurassic Ula formation for tie back to the Ula platform. Secondary reservoir\r\npotential existed in both the middle Jurassic and the uppermost part of the\r\nTriassic.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 7/12-10 was spudded with the\r\nsemi-submersible installation Ross Isle on 8 July 1991 and drilled to TD at 3667\r\nm in the Triassic Skagerrak Formation. After the 30" conductor was set at\r\n167 m, a 17 1/2" pilot hole was drilled without riser to 950 m. No\r\nindications of shallow gas were observed. The well was drilled with seawater\r\nand hi-vis slugs down to 948 m, with Ancoquat water based mud from 948 m to\r\n2730 m, and with KCl/polymer mud from 2730 m to TD. The inhibitive Ancoquat mud\r\nsystem was tested for the first time on the Norwegian Continental Shelf in this\r\nwell. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eShows of oil were observed from 3010 m to\r\n3100 m in the Tor limestone. Subsequent intermediate logs however indicated\r\nthat there was not sufficient quantity of oil to warrant testing the limestone.\r\nTop Mandal formation was encountered at 3531 m drilled depth/3538 m logged\r\ndepth. Top Ula formation was seen at 3620m drilled depth/3627 m logged depth.\r\nThis was 56 m deeper than prognosed, and the formation was also ca 30 m thinner\r\nthan expected. The Ula sandstone was found water bearing with no shows and it\r\nwas not in pressure communication with the main Ula field. Top Triassic was\r\nidentified at 3641.5 m logged depth. It was water bearing with no shows.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eTwo conventional cores were cut from 3616\r\nm to 3628 m and 3628 m to 365","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"713","properties":{"OBJECTID":713,"wlbNpdidWellbore":1558,"wlbName":"1/9-6 SR","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 1/9-6 SR is a re-entry of well 1/9-6\r\nS on the north-west flank of the Tommeliten Gamma structure in the Feda Graben\r\nin the southern North Sea. Well 1/9-6 S was suspended in December 1984 as a\r\npossible producer for the Tommeliten Gamma. The objective of the re-entry was\r\nplugging.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 1/9-6 S was re-entered with the\r\nsemi-submersible installation Ross Rig on 6 April 1991. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was plugged and permanently\r\nabandoned on 20 April 1991.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eTesting\u003c/span\u003e\u003c/b\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo drill stem test was performed.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"714","properties":{"OBJECTID":714,"wlbNpdidWellbore":1560,"wlbName":"16/4-2","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 16/4-2 was the second well on the\r\nblock and last commitment well for license 087. The well is located in a\r\ncentral position on the structure, close to the western border of the block.\r\nThe main target was sands of Middle Eocene age supposed to be present within a\r\nmounded seismic sequence that constitutes the eastern part of the Alpha\r\nprospect in the Sleipner Field. The primary objective of the well was to prove\r\noil in the Eocene sandstones. Secondary objectives were to confirm the seismic\r\ninterpretation and the geological model for the Eocene sand; to test a possible\r\nsmall closure at top Heimdal Formation level; to obtain additional information\r\non migration paths in the area; to confirm the seismic interpretation of the\r\nbasal Cretaceous/ Late Jurassic sequence; and to test the hydrocarbon potential\r\nof possible Late Jurassic sand accumulations. Shallow gas could be expected at\r\n537 m. This corresponds to the level of the blowout in well 16/4-1. A possible\r\nshallow gas content could occur in a thin sand layer at 685 m, which was\r\ncorrelated from well 16/4-1.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 16/4-2 was spudded with the\r\nsemi-submersible installation Vildkat Explorer 29 June 1990 and drilled to 3117\r\nm in Intra Draupne Formation sandstones. No shallow gas was encountered in the\r\nwell; the gas zones were drilled with riser and mud weight 1.22 rd to control\r\nthe gas. The well was drilled with seawater and hi-vis pills down to 1710 m and\r\nwith KCl Polymer mud from 1710 m to TD. Drilling went without any significant\r\nproblems apart from the 13 3/8" casing getting stuck at 1450 m. To resolve\r\nthis problem diesel EZ pills were used in the well bore. This affected gas\r\nreadings throughout the well below 1710 m and gave some spuriously high readings.\r\nThe 13 3/8" casing shoe was finally set at 1683 m, and the casing\r\ncemented. The Eocene Grid formation sandstone came in at 1913 m, approximately\r\n88 m deeper than prognosed. No hydrocarbons we","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"715","properties":{"OBJECTID":715,"wlbNpdidWellbore":1561,"wlbName":"7120/10-2","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eBlock 7120/10 is situated on the\r\nsouthwest margin of the Hammerfest Basin with the Tromsø Basin to the west, and\r\nthe Troms-Finnmark Platform to the south. Well 7120/10-2 was designed to drill\r\nValanginian submarine fan sandstones, where the hydrocarbon trap is formed by\r\nup dip sand pinch out to the south and west combined with structural dip to the\r\nnortheast. The reservoir was prognosed to be penetrated at 2080 m sub sea. The\r\nsource kitchen for the prospect was expected to be the Hekkingen Formation of\r\nLate Jurassic, which is good to rich source rocks and contains oil prone\r\nkerogen. Surface to 214 m subsea could contain boulders and thus cause drilling\r\nproblems. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 7120/10-2 was spudded with\r\nthe semi-submersible installation Byford Dolphin on 20 July 1990 and drilled to\r\nTD at 2500 m in the Late Jurassic Hekkingen Formation. Three incidents delayed\r\nthe drilling for a total of 13.5 days: 1) A boulder bed in the 36" section\r\nmade it necessary to make a trip to change the BHA. The old hole could not be\r\nlocated on this wiper trip so the string was pulled to re-spud; 2) A wellhead\r\nconnector leak needed to be diagnosed and repaired; 3) Logs hung up at ledges\r\nformed when the shale/ claystone was washed out while resistant limestone were\r\nnot. As a consequence of the latter no wire line logs were obtained over the\r\ninterval 2106 m to 1935 m. This interval comprises predominantly shale but does\r\ninclude two sandstone beds (2052 m to 2059 m and 2036 m to 2038 m). The well\r\nwas drilled with seawater down to 523 m and with lignosulphonate/seawater/gel\r\nfrom 523 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well penetrated the primary\r\nobjective, Valanginian sandstones, at 2125 m within the Knurr Formation. These\r\nreservoir quality rocks comprised of sandstones with minor interbedded\r\nsiltstones and shales for a thickness of 178 m down to the contact with the\r\nLate Jurassic Hekkingen Shale at 2303 m. These reservoir sands all proved water\r","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"716","properties":{"OBJECTID":716,"wlbNpdidWellbore":1562,"wlbName":"30/6-9 R","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 30/6-9 R is a re-entry of well\r\n30/6-9 on the Gamma structure of the Oseberg Field. The objective of the\r\nre-entry was plugging and permanent abandonment. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 30/6-9 was re-entered with the with\r\nthe semi-submersible installation Polar Pioneer on 9 May 1990 \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was plugged and permanently\r\nabandoned on 12 May 1990.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eTesting\u003c/span\u003e\u003c/b\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo drill stem test was performed. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"717","properties":{"OBJECTID":717,"wlbNpdidWellbore":1563,"wlbName":"7/11-10 S","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 7/11-10 S was designed to drill the\r\n7/11-A structure on the Mime Field, on the eastern margin of the Central\r\nGraben. The structure is salt induced and consists of a northern, western,\r\neastern and a southern compartment. Oil is proven in the northern compartment\r\nby the 7/11-5 well in the Late Jurassic Ula formation sandstone. The reservoir\r\nsandstone was deposited in a shallow marine environment mainly by storm\r\nepisodes into an approximately 100 km long and 20 km wide "fairway".\r\nShales of the Late Jurassic Farsund- and Mandal formations make up the\r\ncap-rock. The well was to be vertical down to 2002 m MSL and then kicked off\r\ntowards the target with an angle of 33.28 degrees. The primary objective was a\r\nlong term test production from the oil-bearing Ula formation of Area 1 in the\r\nnorthern compartment. Secondary objective was to improve the geological\r\ncontrol, and coring was supposed to give good information about the silica\r\ncementation above and below the OWC. Shallow gas was indicated in the interval\r\nfrom 318 m - to 425 m MSL.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eAppraisal well 7/11-10 S was spudded with\r\nthe semi-submersible installation Transocean 8 on 5 July 1990 and drilled to TD\r\nat 4566 m in the Triassic Smith Bank Formation. No shallow gas of importance,\r\nonly background gas, was encountered while drilling. Gumbo problems were\r\nencountered in the upper part of the 17 1/2" hole, but hole conditions\r\nimproved after increasing the mud weight. The well was kicked off at 2010 m in\r\n40° direction, and the angle built to 35° at 2610 m. While pulling out, the bit\r\ncame out with three cones lost. The string got stuck at 3740 m. Fishing\r\noperation was unsuccessful, and a cement plug was set above the fish. The hole\r\nwas kicked off from the cement plug at 3550 m and sidetracked. No severe\r\nproblems were experienced in the last part of the hole except from low\r\npenetration rate at times and some tight spots on the bit trips. The top hole\r\nwas dr","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"718","properties":{"OBJECTID":718,"wlbNpdidWellbore":1600,"wlbName":"35/9-2","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 35/9-2 was designed to drill on the\r\nA-Structure in block 35/9 which is located in the northern part of the Horda\r\nPlatform, in the footwall of the Sogn Graben boundary fault system. The well\r\nwas drilled as a combined appraisal/wildcat well. The primary objective of the\r\nwell was to appraise the hydrocarbon potential in the Late Jurassic Sognefjord\r\nand Fensfjord Formations, found oil and gas bearing in the 35/9-1 well.\r\nSecondary objective was to test the Middle -Early Jurassic sequence. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe total depth of the well was prognosed\r\nto 2830 m RKB, approximately 30 m into the Caledonian basement.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat/Appraisal well 35/9-2 was spudded\r\nwith the semi-submersible installation Vildkat Explorer on 1 January 1991 and\r\ndrilled to TD at 2885 m in Caledonian basement. Due to hole angle problems, the\r\nwell had to be re-spudded twice before drilling proceeded. No shallow gas or\r\nboulders were observed while drilling. In order to penetrate the target within\r\nthe given tolerances, a kick-off was made at 1039 m. This resulted in a\r\ndeviation of up to 14 deg. at 1287 m and TVD 8 m less than measured depth at\r\nfinal TD. The well was drilled with seawater and hi-vis pills down to 1018 m\r\nand with KCl/polymer from 1018 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well encountered oil and gas bearing\r\nsandstones from 2095 m in the Late Jurassic reservoirs. The gas/oil contact was\r\nfound at 2324 m and oil was found down to 2341 m in the Fensfjord "C"\r\nFormation. Net pay gas zone was calculated to 171.26 m and net oil pay zone\r\ncalculated to 13.13 m. The oil/water contact was not seen, but from\r\nextrapolation of RFT pressure gradients the OWC was estimated at 2367 m in the\r\nFensfjord Formation. The best reservoir sand was found in the Sognefjord\r\nFormation. The Middle and Early Jurassic formations were penetrated and found\r\nwater bearing. Above the Late Jurassic reservoirs only two weak shows were\r\nrecorded in cuttings from thin sandstone stringers ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"719","properties":{"OBJECTID":719,"wlbNpdidWellbore":1604,"wlbName":"6407/6-4","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 6407/6-4 drilled the Mikkel\r\nStructure in the Bremstein Fault Complex, which separates the Trøndelag\r\nPlatform in the east from the Halten Terrace in the west. The structure is an\r\nanticline aligned north-south. The well was planned to reach a total depth of\r\n3150 m. There were no anomalous amplitudes at the planned well location, but there\r\nwas an indication of shallow gas at 401 to 505 m. The purpose of drilling was\r\nto test the possibility of a significant oil leg in the southern part of the\r\nMikkel Structure and to test the communication between the Garn- and Ile Formations\r\nin the southern part of the structure.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eAppraisal well 6407/6-4 was spudded 31\r\nOctober 1990 by the semi-submersible installation Ross Rig and drilled to TD at\r\n3126 m in Early Jurassic sediments of the Åre Formation. The well was started\r\nwith a 9 7/8" pilot hole down to 1088 m due to the possibility of shallow\r\ngas. No shallow gas was encountered. The well was then opened up and drilled with\r\nsea water and viscous pills down to 1085 m, and with KCl/polymer mud from 1085\r\nm to TD. No significant technical problems were encountered in the operations. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe Garn Formation was penetrated at 2651\r\nm (26 m deeper than prognosis) and was 101 m thick. The reservoir quality of\r\nthis sandstone was good. The only oil shows recorded during the drilling were\r\nin the Garn Formation at 2658 - 2686 m. These were of a poor quality consisting\r\nof very dull yellow direct fluorescence, weak light yellow streaming cut fluorescence\r\nwith a milky cut colour. The shows were patchy with no oil bleeding or\r\nhydrocarbon odour being noted. \u003c/p\u003e\r\n\r\n\u003cp\u003eTwo cores were cut in the well, the first\r\nin the Garn Formation of the Fangst Group and the second in the Åre Formation\r\nof the Båt Group, both with 100% recovery. The RFT tool was run in the Båt and\r\nFangst Groups. A comparison of pore pressure in the Ile and Tilje Formations\r\nshow they have slightly higher pore press","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"720","properties":{"OBJECTID":720,"wlbNpdidWellbore":1613,"wlbName":"2/7-24","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 2/7-24 was drilled on the west\r\nValhall Prospect, a Late Jurassic structure located in the Feda Graben on the\r\nwest side of the Central Trough near the Skrubbe Fault. The main objective was\r\nthe Eldfisk Formation sandstones, a mass flow deposit located on the east side\r\nof the fault. A secondary objective was sandstones associated with a seismic\r\nhorizon called the Intra Volgian Marker. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 2/7-24 was spudded by the\r\nsemi submersible rig Ross Isle 7 November 1990 and drilled to TD at 5023 in the\r\nLate Jurassic Farsund Formation. No shallow gas was encountered in this well. At\r\nca 3050 m, in the 5 7/8" hole section, the inclination started to increase\r\nto a maximum of 20 deg where after the inclination decreased to 12,5 deg at TD.\r\nThe well was hampered by bad weather, malfunction of BOP, hole problems with\r\nloss of mud, and problems with running logging equipment properly. The well was\r\ndrilled with sea water and hi-vis pills down to 465 m, with ester-based Petrofree\r\nmud from 465 m to 3042 m, and with oil based mud from 3042 m to 3388 m. Below\r\n3388 m the mud was switched from oil based to water based in an effort to\r\nreduce the mud losses. Water based mud was used down to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe base Cretaceous unconformity was\r\nencountered at 3195 m. The well penetrated 122 m of Mandal Formation and\r\ncontinued through 1706 m of Farsund Formation without reaching its base. Hence an\r\n1828 m thick Late Jurassic section was penetrated, a record at the time of\r\ndrilling. The Late Jurassic lithology was primarily mudstone with subordinate\r\namounts of thinly bedded sandstone and limestone. The primary objective was\r\nencountered approximately at 4069 m, 174 m higher than prognosed. No reservoir\r\nquality clastic mass flow dep","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"721","properties":{"OBJECTID":721,"wlbNpdidWellbore":1643,"wlbName":"7229/11-1","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 7229/11-1 was\r\nthe first well drilled in Production Licence 183 following the interpretation\r\nof a 3D seismic survey acquired in 1991. The well is situated on the\r\nnortheastern part of the Finnmark Platform. The target of the well was the\r\n\"Castor\" prospect, consisting of two Permian-Carboniferous (Sakmarian\r\nto Asselian age) carbonate build-ups confined in combined dip-closed and\r\nstratigraphic traps. The objectives were to test the hydrocarbon potential of\r\nthe carbonate build-ups, referred to as Carbonate 1 and Carbonate 2\r\nrespectively, to acquire additional information on the Permian-Carboniferous of\r\nthe Finnmark Platform, and to calibrate the seismic expression of the\r\nbuild-ups.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eExploration well was\r\nspudded with the semi-submersible installation \"Ross Rig\" on 9 August\r\n1993 and drilled to a total depth of 4630 m in limestone of Middle - Lower?\r\nCarboniferous age. The well was drilled with sea water and hi-vis pre-hydrated\r\nbentonite pills down to 1098 m, with KCl / polymer mud from 1098 m to 3012 m,\r\nand with a high-temperature KCl / Polymer mud from 3012 m to TD. The soft\r\nseabed did not present anchoring problems. No shallow gas was encountered.\r\nDrilling problems were experienced in the interval 339 m & 379 m. A seismic\r\nmarker (black loop) corresponds to the top of this interval, which is\r\ninterpreted as a boulder rich sequence. Drilling problems could have been due\r\nto boulders to fall into the hole and become wedged, thus causing sticking. The\r\npredicted carbonate build-up targets were encountered but were not reservoir\r\nfacies. Carbonate 1 was confirmed to be build-up / build-up flank facies;\r\nCarbonate 2 was found to be carbonate platform facies. No hydrocarbon shows\r\nwere encountered in the well. Nine cores totalling 180.9 metres length were successfully\r\ncut and retrieved from the Permian-Carboniferous. No hydrocarbon shows were\r\nencountered in the well. The well was plugged and abandoned as a dry hole on 15\r\nDec","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"722","properties":{"OBJECTID":722,"wlbNpdidWellbore":1644,"wlbName":"25/1-8 SR4","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe Frigg Field was discovered by well\r\n25/1-1 in 1971 and set in production in May 1977. Well 25/1-8 S was drilled in\r\nthe summer of 1985 to monitor changes in gas/fluid contact, uncover\r\npermeability barriers and pressure gradients in the Frigg Formation, refine the\r\ngeological model, and provide ties for seismic interpretations. Before\r\nproduction started the Frigg Field fluid contacts were: OWC = 1955.9 m TVD MSL\r\nand GOC = 1948.2 m TVD MSL. In July 1985 in 25/1-8 S found the oil-leg to be\r\nall swept with the exception of a very thin oil-layer lifted to 1903.5 m TVD\r\nMSL, 2 m below the new gas/liquid contact, which was now a gas/water contact\r\n(GWC) at 1901.3 m TVD MSL. The objective of the fourth re-entry well 25/1-8 SR4\r\nwas to monitor further changes in the GWC and to permanently plug and abandon\r\nthe well.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 25/1-8 S was re-entered\r\n(25/1-8 SR4) with the semi-submersible installation West Vanguard on 3 April 1991.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe GWC was found at 1897.5 m TVD MSL, the\r\nsame as in 25/1-8 SR3. This showed a similar situation as in well 25/1-7 and\r\ncorresponding re-entries ca 2.5 km to the north. It showed that gas drainage\r\nwas blocked by shale barriers over large areas in the central parts of the\r\nfield.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo cores were cut. The RFT was run, and 6\r\npressure points were taken but no fluid samples.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was permanently abandoned on 14\r\nApril 1991 as a gas appraisal well.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eTesting\u003c/span\u003e\u003c/b\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo drill stem test was performed.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"723","properties":{"OBJECTID":723,"wlbNpdidWellbore":1667,"wlbName":"2/1-9","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 2/1-9 was drilled on the Gyda South structure,\r\na fault/dip closure in the Late Jurassic fairway on the eastern flank of the\r\nCentral Graben, 6 km south of the Gyda Field. The main objective of the well\r\nwas to test the Late Jurassic "Gyda sandstone" (Ula Formation) target\r\nand prove a volume of oil that was commercial as a tie back development to the\r\nGyda platform. Secondary reservoir potential existed in both the Middle\r\nJurassic and in the uppermost part of the Triassic. Estimated TD was 4275 m TVD\r\nRKB.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eAppraisal well 2/1-9 was spudded with the\r\nsemi submersible rig Ross Isle 15 March 1991 and drilled to TD at 4298 m in the\r\nlate Permian Zechstein Group. No significant problems were encountered in the\r\noperations. No shallow gas was detected. The well was drilled with seawater and\r\nhigh viscosity slugs down to 900 m, and with Aquamul ether-based invert emulsion\r\nmud system from 900 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eA 59 m Forties Formation sandstone\r\nsequence was encountered at 2923 m in the Late Paleocene and another ca 30 m thick\r\nsandstone sequence at 3025 m within the Lista Formation. Top Mandal Formation\r\nwas encountered at 4013.5 m, 10.5m deeper than predicted. Top Ula Formation was\r\nencountered hydrocarbon bearing from 4048 to 4209 m, which was 111 m thicker\r\nthan expected. The OWC was interpreted from logs to be at 4137.0 m, while the\r\ncores taken had good oil shows all through the cored section, i.e. down to 4153\r\nm. No reservoir sections were encountered in the Middle Jurassic. No Triassic\r\nsediments were penetrated by the well. \u003c/p\u003e\r\n\r\n\u003cp\u003eFive cores were cut continuously from\r\n4019 m to 4153 m with 100% recovery. Core 1 covered the lower part of the\r\nMandal, Farsund, and the upper part of the Ula Formation. Cores 2, 3, 4 and 5 were\r\ncut in the Ula Formation. Good oil shows was observed throughout the cored\r\nsection of the Ula sandstone. RFT fluid samples were taken at 4088.7 m (oil),\r\n4137.0 m (oil), 4151 (water), and 41","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"724","properties":{"OBJECTID":724,"wlbNpdidWellbore":1668,"wlbName":"2/11-6 SR","wlbHistory":"\r\n\r\n\r\n\r\n\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 2/11-6 SR is a re-entry of well\r\n2/11-6, which confirmed oil in the Tor and Hod Formation on the Hod East\r\nstructure. The objective of the re-entry was testing and completion as a\r\nproduction well.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 2/11-6 SR was re-entered\r\nwith the jack-up installation on 19 July 1990. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAfter testing the well was re-classified\r\nto development well 2/11-A-6 on 13 August 1992.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eTesting\u003c/span\u003e\u003c/b\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eA production test was performed.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"725","properties":{"OBJECTID":725,"wlbNpdidWellbore":1669,"wlbName":"31/5-4 S","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 31/5-4 S was drilled in a southern,\r\ndown flank compartment of the Troll West Gas province, 1000 m north west of\r\nwell 31/5-2. The Troll West Province is an easterly rotated fault block where\r\nthe southern part is approximately 10 x 15 km with a general dip of 1 to 2\r\ndegrees at reservoir level. The primary objective was to provide a penetration\r\nhole for a later test production in a horizontal side track hole in the 13 m\r\noil layer in the Sognefjord Formation. The test production should confirm the\r\noil production potential from the Troll West Gas Province; obtain dynamic data\r\nfrom a potential development type well and obtain static reservoir and\r\ngeological data to provide proper understanding of well behaviour. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 31/5-4 S was spudded with the\r\nsemi-submersible installation Transocean 8 on 13 September 1990 and drilled to\r\nTD at 1909 m in the Middle Jurassic Fensfjord Formation. No shallow gas was\r\nencountered, as prognosed. The well was drilled vertical down to 1040 m from\r\nwhere angle was built up to 53 deg at 1571 m. Tight hole problems were\r\nexperienced at several depths, and at 1360 m the hole packed off and mud return\r\nwas temporary lost. The well was drilled with seawater and hi-vis pills down to\r\n940 m and with KCl/polymer polyacrylamide mud from 940 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe Sognefjord Formation was penetrated from 1619 m (1535.4 m TVD RKB) to 1830 m\r\n(1660 m TVD RB). The formation was gas filled down to 1670 m (1535.4 m TVD RKB)\r\nand oil filled from there down to 1692.3 m (1567.2 m TVD RKB).\u003c/p\u003e\r\n\r\n\r\n\r\n\r\n\r\n\u003cp\u003eThe well bore was plugged back to 1496 m\r\nfor sidetracking. It was permanently abandoned on 10 October 1990 as a gas and\r\noil appraisal well.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was performed\u003c/p\u003e\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"726","properties":{"OBJECTID":726,"wlbNpdidWellbore":1672,"wlbName":"25/11-14 S","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 25/11-14 S was drilled centrally on\r\nthe Balder Field on the Utsira High in the North Sea. This field was discovered\r\nin 1967 by the 25/11-1 well, and was the first well on the Norwegian shelf that\r\nproved oil. Well 25/11-14 S was planned to be completed for a long term test by\r\nthe FPV Petrojarl 1. The well was planned deviated in order to avoid possible\r\nshallow gas at 235 m, 254 m, and 515 m. The main objective of this well was to\r\ntest two Paleocene Heimdal Formation sands; the IB4 sand at 1863 m and the IB3 sand\r\nat 1897 m. The Heimdal Formation had previously proved oil-bearing in the three\r\nneighbouring wells 25/11-6, -7, and -8. Eocene sands constituted a secondary\r\nobjective for testing. Based on data from surrounding wells, no abnormal\r\npressure was expected. The surface location and well trajectory for this well,\r\nwas designed so that a later plug-back and sidetrack to a horizontal completion\r\ncould be accomplished.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 25/11-14 S was spudded with\r\nthe semi-submersible installation Byford Dolphin on 13 September 1990. During\r\nsetting of the 30" casing a fatal accident occurred as one of the\r\nroughnecks was hit by the rig tongs and perished on the drilling floor. A 9\r\n7/8" pilot was drilled with MWD from 189 m to check possible shallow gas.\r\nSands were detected, but they contained salt water only. The planned deviation was\r\ninitiated at 950 m. While POOH for coring the Heimdal Formation sand, the pipe\r\nbecame stuck (packed off by sloughing shales) and the well bore abandoned at a\r\nTD of 1908 m (1749 m TVD), 5 m into the target Heimdal Formation. The well was\r\ndrilled with seawater down to 452 m and with KCl/polymer/gel mud from 452 m to\r\nTD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe secondary target Eocene sands were\r\nnot pre","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"727","properties":{"OBJECTID":727,"wlbNpdidWellbore":1673,"wlbName":"30/9-11","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 30/9-11was drilled on the eastern\r\nsegment of the J-structure on the Oseberg Sør field in the North Sea. Neighbouring\r\nwells 30/9-9 on the J-West and 30/9-5 S on the J-Central proved oil and gas,\r\nrespectively. The primary objective of well 30/9-11 was to prove reservoir\r\nsands and oil within the Brent Group of the J-East segment and define oil/water\r\ncontacts for the Tarbert/Ness and Oseberg-Rannoch-Etive reservoirs. The well\r\nwas planned to be drilled 50 m into the Dunlin Formation to a total depth of\r\napproximately 2540 m.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 30/9-11 was spudded with the\r\nsemi-submersible installation Vildkat on 27 October 1990 and drilled to TD at 2570\r\nm in the Early Jurassic Drake Formation. No significant problem was encountered\r\nin the operations. The well was drilled with spud mud down to 922 m and with\r\nKCl/polymer mud from 922 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eTop Viking Group, Heather Formation was\r\nencountered at 2291 m. Top Brent Group, Tarbert Formation was encountered at\r\n2384 m. The Brent Group was entirely water bearing. Poor, patchy shows on thin\r\nsandstone lamina in the Heather Formation were the only indications of\r\nhydrocarbons in the well. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eFour cores were cut with good recovery.\r\nCore 1 was cut from 2382 m to 2403 m in the Tarbert and Ness formations, cores\r\n2 and 3 were cut from 2450 to 2464.5 m in the Ness Formation, and core 4 was\r\ncut from 2484 m to 2511 m in the Ness and Rannoch formations. RFT water samples\r\nwere taken at 2493 m in the Ness Formation.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was plugged back for\r\nsidetracking on 19 November 1990. It is classified as a dry well.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eTesting\u003c/span\u003e\u003c/b\u003e","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"728","properties":{"OBJECTID":728,"wlbNpdidWellbore":1677,"wlbName":"34/7-16 R","wlbHistory":"\u003c\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 34/7-16 R is a re-entry of well 34/7-16,\r\nwhich was suspended due to time schedule for the rig. The well is located\r\nbetween the Statfjord and Snorre Fields on Tampen Spur in the Northern North\r\n Sea. The purpose of the re-entry was to test the hydrocarbon-bearing Brent\r\nGroup reservoir and also to drill through and test the Statfjord Formation.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 34/7-16 was re-entered (34/7-16 R)\r\non 4 September 1990 by the semi-submersible rig Treasure Saga and drilled through\r\nthe Statfjord formation to TD at 2980 m, 35 m into the Late Triassic Lunde\r\nFormation. The well was drilled with KCl mud.\u003c/p\u003e\r\n\r\n\u003cp\u003eBoth the Statfjord formation and the Lunde\r\nFormation proved to be water bearing. The Statfjord Formation (2821 - 2945 m) had\r\nan estimated average log porosity of 21.7% and a net to gross ratio of 0.56.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well suspended on 15 October 1990 as an oil appraisal.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThree DST tests were performed in well\r\n34/7-16 R.\u003c/p\u003e\r\n\r\n\u003cp\u003eDST 1 tested the interval 2821 - 2837 m\r\nin the Statfjord Formation. The test was mainly designed to get representative\r\nsamples of Statfjord Formation water. The initial pressure and temperature at\r\nthe top perforation was 406 bar and 102 deg C. Clean water with very little gas\r\nwas produced. The gas gravity was 0.64 (air = 1). It was not possible to\r\nmaintain stable flowing conditions due to plugging at the choke manifold, but a\r\nflow-rate of 1450 m3/day at a wellhead pressure of 105 bar was measured at the\r\nend of the 12 hrs flow period. \u003c/p\u003e\r\n\r\n\u003cp\u003eDST 2 tested a four metres zone from 2454\r\n- 2458 m in the Rannoch Formation. The main objective was to evaluate the\r\nlateral extension of the two calcite cemented layers (2451 - 2453 and 2459 -\r\n2461 m). The initial pressure and temperature at the top perforation was 366\r\nbar and 90 deg C. Oil with a GOR of 55 Sm3/Sm3 was produced. The gas gravity\r\nwas 0.75 (air = 1) and the CO2 content was 0.27%. After a clean-up period, the\r\nw","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"729","properties":{"OBJECTID":729,"wlbNpdidWellbore":1679,"wlbName":"2/7-25 S","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 2/7-25 S was drilled on the Embla\r\nstructure in the southern North Sea. The objective of the well was to prove the\r\nsouth-eastern continuation of the Embla reservoir sands seen in 2/7-20 and\r\n2/7-21S, and if successful establish another drainage point for future\r\ndevelopment.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 2/7-25 S was drilled from\r\na temporary subsea template located over the 2/7-20 well, using the\r\nsemi-submersible installation West Delta. It was spudded on 29 November 1990\r\nand drilled to TD at 5177 m (4560 m TVD) in pre-Jurassic rocks. The well was\r\ndeviated to a target location 2072 m southeast of the wellhead. I was drilled\r\nwithout any major problems. Shallow gas was encountered in four sand intervals\r\nin the 26" hole section over the interval 595 -652 m. A minor gas flow was\r\ncontrolled using 11.0 ppg kill mud with high viscosity pills. The well was\r\ndrilled with sea water down to 780 m, with ester emulsion based Petrofree mud\r\nfrom 780 m to 4557 m, and with oil based Enviromul mud from 4557 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eTop Jurassic, Mandal Formation was\r\nencountered at 4711 m. The Jurassic consisted of 117 m Mandal Formation, 112 m\r\nFarsund Formation, and 214 m Eldfisk Formation at the base. Under the Eldfisk\r\nFormation, at 5157 m (4540 m TVD), a pre-Jurassic section was encountered. Oil\r\nshows were detected from 1594 m to 1786 m, with good shows from 1704 m to 1750\r\nm at top Hordaland Group. Further oil shows were seen throughout all parts of\r\nthe limestone section but were concentrated in the intervals 3470 m to 3484 m\r\nin the Ekofisk Formation and 4328 m to 4435 m in the Hod Formation. In addition\r\nsolid bitumen staining was described on cores from the Mandal and Eldfisk\r\nFormations.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eA ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"730","properties":{"OBJECTID":730,"wlbNpdidWellbore":1680,"wlbName":"15/12-7 S","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 15/12-7 S was designed to drill in\r\nLate Jurassic Oxfordian sandstones on the Theta North prospect in the\r\nsoutheastern part of the PL 116 licence area. The structure is a rotated fault\r\nblock dipping southeast and bound to the west and north by faults. Based on\r\nmapping and inversion studies of the 15/12-5 well and the Beta-east structure\r\nit was likely that an Oxfordian sequence was present at the Theta structure.\r\nHowever, it could not be excluded that the Oxfordian reservoir had been eroded\r\nfrom top of the structure. The main objective of well 15/12-7 S was to test the\r\npotential for hydrocarbons in the Oxfordian sandstones. A secondary objective\r\nwas to test possible Triassic sandstones. Seismic anomalies at 441 m and 792 m\r\nstrongly suggested shallow gas. Because of this the spud location was set\r\noutside of the planned location.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 15/12-7 S was spudded with\r\nthe semi-submersible installation Deepsea Bergen on 6 November 1990 and drilled\r\nto TD at 3529 m in the Triassic Smith Bank Formation. Problems\r\nwere encountered in building and dropping angle in deviated well section (13\r\n3/8" to 9 5/8"). Pipe stuck at 2703 m and 2720m but came free. Stuck\r\nagain with FMT-tool at 3425m. The tool was left in the hole. The well was drilled with seawater and bentonite pills down to 173\r\nm, with seawater and CMC EHV from 173 m to 620 m, with gypsum/PAC from 620 m to\r\n3027 m, and with gel/polymer/lignosulphonate from 3027 m to TD. No shallow gas\r\nwas encountered at 441 m, but from MWD gas was encountered at 775 m. Several\r\nmisruns while logging were experienced. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe Oxfordian reservoir sandstone (Intra\r\nHeather Sandstone) came in at 3025 m, 25.5 m shallower than prognosed. No\r\nhydrocarbons were encountered. One 27 m conventional core was cut from 3028 m\r\nto 3055 m in the reservoir unit with 94.4 % recovery. A total of 100 sidewall\r\ncores were attempted of which 93 were recovered. No sidewall cores were\r\natt","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"731","properties":{"OBJECTID":731,"wlbNpdidWellbore":1681,"wlbName":"7/11-10 SR","wlbHistory":"\r\n\r\n\u003ch2\u003eWellbore history \u003c/h2\u003e\r\n\r\n\u003cp\u003e \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 7/11-10 SR is a re-entry of the\r\n7/11-10 S well on the Mime Field. The purpose of the re-entry was testing and\r\ncompletion. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell bore 7/11-10 S was re-entered\r\n(7/11-10 SR) with the semi-submersible installation Vildkat Explorer on 25\r\nSeptember 1990. The well was completed for a long term test in the Ula\r\nFormation Sandstone.\u00A0\u00A0 \u003c/p\u003e\r\n\r\n\u003cp\u003eAfter testing the well was plugged and\r\npermanently abandoned on 24 October 1990 as an oil appraisal.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was tested from the interval\r\n4347 m through 4381 m (4016.6-4048.9 m TVDMSL). The maximum temperature during\r\nthe test was 164 deg C measured at depth 4048 m. The well was reclassified to test production well 7/11-T-10 S and produced from October 1990 to November 1993.\u003c/p\u003e\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"732","properties":{"OBJECTID":732,"wlbNpdidWellbore":1683,"wlbName":"34/8-4 S","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 34/8-4 S is located on the Visund\r\nField, A structure where previous wells 3/8-1, 3/8-3, and 3/8-3 A had proved\r\nhydrocarbons in the Brent Group. The main target in 34/8-4 S was the\r\nhydrocarbon potential in the Lomvi Formation on the A-structure. Secondary\r\ntargets were the hydrocarbon potentials of the Statfjord and Lunde B/C\r\nformations on the A south compartment. Pressure measurement should be acquired\r\nfrom the Lunde- and Lomvi Formations in order to evaluate the sealing potential\r\nof the Middle to Late Triassic sequence. The well was designed for temporary\r\nabandonment and re-entry as a subsea producer. The well was planned as a\r\ndeviated hole to penetrate top Statfjord, Lunde B/C and the Lomvi Formations\r\nwithin structural closure, leaving more than 10 mill Sm3 oil untested up-dip.\r\nBoulders could be encountered between 350 m and 395 m. Two intervals with\r\npossibility for shallow gas were identified at 446 m and 477 m.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 34/8-4 S was spudded with the\r\nsemi-submersible installation Maersk Jutlander on 6 Desember 1991 and drilled\r\nto TD at 4150 m in rocks of Triassic age. Drilling started with an 8 1/2"\r\npilot hole checking for shallow gas. No boulders or shallow gas was\r\nencountered. Significant technical problems were encountered during drilling of\r\nthis well and one third of the total rig time was counted as down time. The\r\nlongest period of down time occurred after TD in the 17 1/2" hole where\r\n31.6 days were spent repairing the BOP and wellhead. The planned TD at 4478 m\r\nwas not reached due to operational problems. The pipe was backed off at 3936 m\r\nand the borehole was logged from this depth and up to the 9 5/8" casing\r\nshoe. The well was drilled vertical down to ca 2310 m where it started to build\r\nangle up to 30 ° at ca 2680 m. From here to TD the deviation varied between 30\r\n° and 50 °.\u00A0 The well was drilled with spud mud and seawater down to 1165 m,\r\nwith KCl / polymer mud from 1165 m to","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"733","properties":{"OBJECTID":733,"wlbNpdidWellbore":1689,"wlbName":"31/5-4 A","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 31/5-4 A was drilled as a horizontal\r\nside track to well 31/5-4 S in the Troll West oil and gas province. The well\r\nobjective was test production from the 13 m oil layer in the Sognefjord\r\nFormation. The test production should evaluate the oil production potential\r\nfrom the Troll West Gas Province, obtain dynamic data from a potential\r\ndevelopment type well, and obtain static reservoir and geological data to\r\nprovide proper understanding of well behaviour. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell bore 31/5-4 A was kicked off from\r\n31/5-4 S at 1569 m on 10 October 1990, using the semi-submersible installation\r\nTransocean 8. Due to difficulties in building sufficient angle, the well was\r\nplugged back and technically sidetracked from 1604 m. The 9 5/8" casing\r\nwas set horizontally at 1803 m, and the well drilled horizontally for another\r\n800 m to TD at 2603 m in the Late Jurassic Sognefjord Formation. The well was\r\ndrilled with Carbotec oil based mud from kick-off to TD. The horizontal section\r\nwas drilled in the oil bearing part, approximately 1 meter above the oil-water\r\ncontact.\u00A0 No cores were cut and no fluid samples taken. The well was completed\r\nwith a prepacked screen in the horizontal section. A clean-up test and a\r\nproduction logging test was conducted with the Transocean 8 before the well was\r\nsuspended on 13 Dcember 1990 and connected to the vessel Petrojarl I for a\r\nlong-term production test. Well 31/5-4 A is classified as an oil and gas\r\nappraisal well.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was tested from the horizontal\r\ninterval in the Sognefjord Formation beyond the 9 5/8" casing shoe , i.e.\r\n1801-2603 m RKB / 1578.5 m TVD RKB +/- 0.3 m. The measured test data from the\r\nend of the second and final production logging period, with the production\r\nlogging tool (PLT) at 1825 m / 1578.5 m TVD RKB, were reported as follows: Oil\r\nrate = 217 Sm3/day, gas rate = 11869 Sm3/day, water rate = 318 Sm3/day, GOR =\r\n55 Sm3/Sm3, CO2 content = 1%, oil d","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"734","properties":{"OBJECTID":734,"wlbNpdidWellbore":1690,"wlbName":"7120/2-2","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 7120/2-2 was designed to test the\r\nMesozoic rocks on a down-faulted position, south of the Loppa High. Well\r\n7120/1-2 about 12.5 km to the southwest had tested minor amounts of oil in the\r\nEarly Cretaceous. This was a new play concept on the Barents Shelf related to\r\nstructural/stratigraphic combination traps as a result of wedge sedimentation\r\nin conjunction with the Kimmeridgian tectonic phase. The main objectives of the\r\nwell were to test the prospectivity of the Early Cretaceous fan systems (wedge\r\nI and II) in an optimal position, and to test the prospectivity of the Middle\r\nJurassic Stø Formation. The pore pressure was expected to be normal throughout\r\nthe well. Shallow gas warnings were given for two levels down to 1437 m. A fault\r\nwith displacement less than 10 m was seen at the planned well location at depth\r\nca 565 m.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 7120/2-2 was spudded with\r\nthe semi-submersible rig Polar Pioneer on 27 January 1991 and drilled to TD at\r\n2800 m in Early Jurassic sandstones of the Stø Formation. The well was drilled\r\nwith spud mud down to 800 m and with KCl polymer mud from 800 m to TD. No\r\nshallow gas intervals were penetrated. No major problems were experienced while\r\ndrilling the hole.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe first wedge, in the Kolmule\r\nFormation, was penetrated at 1712 m. The second wedge, expected to be\r\nsandstones of the Knurr Formation, was penetrated at 2125 m. Oil shows, mostly\r\nweak, were recorded from the top of this wedge and down to ca 2700 m. The\r\nstrongest shows were recorded on a core from 2393 m to 2403 m. Geochemical\r\nanalyses proved a ten metre claystone sequence with excellent source rock\r\npotential at 2120 m on top of the wedge; around 6% TOC and Hydrogen Index\r\naround 480 mg HC/g TOC. Vitrinite reflectance in the sequence is in the range\r\n0.55 to 0.60 % Ro and Tmax around 434 deg C, corresponding to early oil window\r\nmaturity. A second excellent source interval was penetrated in the Late\r\nJurassic Hekkingen Fo","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"735","properties":{"OBJECTID":735,"wlbNpdidWellbore":1691,"wlbName":"25/5-4","wlbHistory":"\r\n\r\n\u003cp\u003eWell 25/5-4 is located approximately in\r\nthe centre between the 5/5-5 Discovery and the Frøy and Skirne Fields in the\r\nnorthern North Sea. The prospect was defined at Intra Statfjord Formation level,\r\nconsisting of two compartments offset by an E-W fault. No significant closure\r\nwas expected at Base Cretaceous. The main target was the Middle Jurassic\r\nVestland Group sandstones. Early Jurassic Statfjord sandstones was secondary\r\ntarget. The expected fluid was most likely oil. No shallow gas was expected.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 25/5-4 was spudded with the\r\nsemi-submersible installation Dyvi Stena on 22 December 1990 and drilled to TD\r\nat 3185 m in Early Jurassic sediments of the Statfjord Formation. Only minor\r\nproblems were encountered during drilling the Hordaland Group. The well was\r\ndrilled with sea water and bentonite down to 1208 m, with a KCl mud from 1208 m\r\nto 2805 m, and with lignosulphonate mud from to 2805 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe results for the main seismic markers\r\nwere close to prognoses (from 17 to 36 m higher than prognosis). Sandy water bearing\r\nreservoirs were encountered in the basal Tertiary Heimdal and Ty Formations.\r\nThe Vestland Group reservoir (Hugin + Sleipner Formations) was encountered from\r\n2895 to 2941 m and was completely filled with a retrograde condensate. Extracts\r\nof core material showed a significant increase in extractable organic matter\r\nbelow 2932 m, and the EOM was significantly more oil-like (saturates > 55%)\r\nthan the upper part of the reservoir. The Statfjord Formation proved good\r\nreservoir quality but was water bearing. Organic geochemical data proved\r\nexcellent source rock characteristics in several levels throughout the\r\nJurassic, with oil prone kerogen in the Draupne and Heather Formations, and gas\r\n- condensate prone kerogen in the Vestland Group and Statfjord Formation. The source\r\npotential of Draupne is similar to the one known in the surrounding wells,\r\nwhile the Heather has better characteristics. The extreme base","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"736","properties":{"OBJECTID":736,"wlbNpdidWellbore":1699,"wlbName":"6407/7-5","wlbHistory":"\r\n\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThe Njord Field is situated in the\r\nsouthern part of the Haltenbanken area in a down faulted position relative to\r\nthe Trøndelag Platform and the Frøya High. Oil had been encountered in previous\r\nwells on Njord in the Ile, Tilje, and Åre Formations. Well 6407/7-5 is located on\r\nthe North II fault segment on the North Flank of the Njord structure. The main\r\nobjectives for the well were to test the resource potential of the Northern\r\nFlank, to clarify the number of production and injection wells needed for\r\ndevelopment, and to verify the reservoir quality and the sealing potential of\r\nfaults. The pore pressure gradient was expected to be maximum 1.54 rd in the\r\nreservoir. Shallow gas warnings were given for 6 levels down to 650 m. Planned\r\nTD was 3725 m \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 6407/7-5 was spudded with the\r\nsemi-submersible installation Transocean 8 on 15 February 1991 and drilled to\r\nTD at 3725 m in Early Jurassic sediments of the Åre Formation. After coring the\r\ninterval 3168 - 3215m the drilling assembly got stuck when running in the hole.\r\nFishing the drilling assembly failed and the well was subsequently plugged back\r\nand side tracked from 3080 m. Indications of shallow gas were found in two of\r\nthe six warned levels. The well was drilled with spud mud down to 1112 m and\r\nwith KCl/polymer mud from 1112 m to TD. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe reservoir sandstones of the Ile, Ror\r\nand Tilje Formations were found to be water bearing. RFT pressures and one\r\nsegregated sample indicated very poor permeabilities in the sandstone intervals\r\ntested. From the data it was not possible to determine whether pressure\r\ncommunication exists between 6407/7-5 and 6407/7-3.\u003c/p\u003e\r\n\r\n\u003cp\u003eSporadic oil shows were recorded on\r\nsandstone stringers in the Nise Formation below 2267 m. Weak oil shows were\r\nrecorded on claystones, limestones and sandstones of the Lysing Formation\r\nbetween 3000 - 3084 m. This interval also had high gas readings with gas peaks\r\nup to 10%. Some oil shows were s","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"737","properties":{"OBJECTID":737,"wlbNpdidWellbore":1702,"wlbName":"2/4-16","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 2/4-16 was drilled on the eastern\r\nmargin of the Feda Graben North of the Albuskjell and Ekofisk Fields in the\r\nNorth Sea. Geologically the area consists of three sub-platforms. These are\r\nseparated by large NW-SE striking normal faults down-faulted to the southwest\r\nand stepping down to the Feda Graben in the southern part of the block. The\r\n2/4-16 well is located in the centre of the licence area on the same down\r\nfaulted segment as the blowout wells 2/4-13, -14 and -15. Shallow gas was\r\npredicted from seismic anomalies at 10 different levels, and several\r\nprecautions and actions were carried out to be able to handle potential\r\ngas-charged shallow gas.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe main objective for the well was to\r\ntest the Late Jurassic, expected to contain a thick sand resting unconformable\r\non the Middle Jurassic. This objective was the basis also for the 2/4-14 well.\r\nA secondary objective for the well was to penetrate the Middle Jurassic and 150\r\nm into the Triassic sequence to test for possible hydrocarbon bearing\r\nsandstones sequences.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well was spudded with the\r\nsemi-submersible installation Treasure Saga on 7 May 1991 and drilled to TD at\r\n4996 m in the Middle Jurassic Bryne Formation. Shallow gas was detected at 522,\r\n606, 628 and 675 m during drilling of 9 7/8" pilot hole. While drilling\r\nthrough very hard chalk rocks in the 12,6" section severe problems with\r\nthe drilling equipment was experienced. The hard rocks also caused 8.5 days of\r\ndelay due to ten washouts and fishing jobs. In addition the vibration together\r\nwith high temperature caused twelve failures to the MWD tools, and also\r\nproblems related to equipment deliveries. When drilling down to 4996 m the top\r\ndrive saver sub had to be changed out due to a washout. During change of saver\r\nsub, the well started flowing uncontrolled up through the drill string, and the\r\ndrill pipe was cut with the shear ram. Fifty-eight days were spent from\r\nshearing the pi","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"738","properties":{"OBJECTID":738,"wlbNpdidWellbore":1703,"wlbName":"25/4-6 S","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 25/4-6 S was planned to prove the\r\nhydrocarbon potential in a structure located on the northern extension of the\r\nHeimdal Ridge. The structure is located in the NE corner of block 25/4, fairly\r\nclose to the Heimdal, Frøy and Frigg Fields. Four-ways closures were mapped on\r\nall levels from the "Near top Frigg sequence" marker to the Base\r\nVestland Group Marker. The structure above the Base Cretaceous Unconformity is\r\na fairly simple dome/mounded feature, while the Vestland Group and deeper\r\nsections consist of an antithetic tilted block. The objective of the well was\r\nto explore all closures down to at least Vestland Group level. The primary\r\ntarget was the Vestland Group; secondary targets were the Frigg and Heimdal\r\nFormations, while the Statfjord Formation was a third, optional target. Based\r\non data from surrounding wells, no abnormal pressure was expected. To achieve\r\nan optimal position in reaching the targets the well was planned deviated. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 25/4-6 S was spudded with\r\nthe semi-submersible installation West Vanguard on 15 April 1991 and drilled to\r\nTD at 4170 m, 41 m into the Statfjord Formation. The well was drilled vertical\r\n(max 2 deg deviation) through the Frigg and Heimdal prospects down to 2424 m. From\r\nhere angle was built up to a maximum of 22.5 deg at 3025 m before it was\r\ndropped off again to 3 deg at final TD. The hole opener cone was lost at 266 m\r\nresulting in 8 days and 15 hours lost time before drilling could be resumed.\r\nThe FMT tool got stuck at 3836 m with fishing unsuccessful. Thus it was decided\r\nto set a cement plug on top of the tool and perform a sidetrack. The well was\r\ndrilled with seawater and viscous pills down to 197 m, with bentonite mud from\r\n197 m to 1220 m, with KCl/polymer mud from 1220 m to 2503 m, and with\r\nlignosulphonate mud from 2503 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe Early Eocene Frigg reservoir was not\r\nfound, and the Palaeocene Heimdal reservoir was water bearing. Top Vestland","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"739","properties":{"OBJECTID":739,"wlbNpdidWellbore":1705,"wlbName":"30/9-11 A","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 30/9-11 A was drilled as a sidetrack\r\nto well 30/9-11 on the J-structure on the Oseberg Sør field in the North Sea.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe vertical 30/9-11 well drilled a dry\r\nBrent group in J-East segment. The sidetrack targeted the J-Central segment and\r\nshould penetrate top of the Brent Group in a down flank position in order to\r\nconfirm deep oil filling of the J-Central segment, where oil previously had\r\nbeen discovered by well 30/9-9. The primary target was the Brent Group.\r\nSecondary target was the Cook Formation.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 30/9-11 A was kicked off from 920 m\r\nin 30/9-11 on 20 November 1990. The well was drilled with the semi-submersible\r\ninstallation Vildkat to TD at 3002 m (2735 m TVD) in Early Jurassic sediments\r\nof the Statfjord Group. Apart from some tight hole problems and close to seven\r\ndays wait on weather operations proceeded without significant problems. The\r\nwell was drilled with KCl/polymer mud from kick-off to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eTop Viking Group, Heather Formation was\r\nencountered at 2513 m and top Brent Group, Ness Formation was encountered at\r\n2553 m. The Ness Formation was water bearing, however moderate oil shows with\r\nstrong petroleum odour was described on cores from top off the Ness Formation\r\ndown to 2570 m. These shows were confirmed by relatively high organic\r\ngeochemical extract yields with oil-mature biomarkers. Poor shows were\r\ndescribed also in Shetland Group limestone from 2455 to 2457 m and in Heather\r\nFormation claystone from 2517 to 2520 m. Otherwise there were no indications of\r\nhydrocarbons in the well.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThree cores were cut in from 2545 to 2582\r\nm in the Heather, Tarbert, and Ness Formation. A fourth core was cut fr","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"740","properties":{"OBJECTID":740,"wlbNpdidWellbore":1711,"wlbName":"6406/12-1 S","wlbHistory":"\r\n\r\n\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 6406/12-1 S was designed to drill\r\nthe Kappa Prospect, which is located west of the Vingleia fault complex and\r\nnorthwest of the Frøya High in the southeastern part of block 6406/12.\r\nStructurally the block is situated in the southern part of the Halten Terrace.\r\nThe prospect was one of several prospective sequences in a Late Jurassic fan\r\ncomplex mapped in the area. The prospect was a stratigraphic trap with no\r\nstructural closure. The primary objective of the well was to test the\r\nhydrocarbon potential of Late Jurassic sandstones in the Kappa prospect.\r\nPossible other sands in the Cretaceous or Late Jurassic were secondary targets.\r\nThe well was also designed to test the geophysical and stratigraphic\r\ninterpretation of the area and improve the geological, palaeontological and\r\ngeochemical understanding. No shallow gas warnings were given for this well.\r\nLarge boulders present in the glacial deposits in the area might cause drilling\r\nproblems in the 36? and 26" hole section. The pore pressure estimates for\r\nthe Late Jurassic were uncertain as one of the correlation wells (6406/8-1)\r\npenetrated highly over-pressured formations and had serious drilling problems.\r\nThe other correlation well (6407/10-2) did not penetrate any highly\r\nover-pressured formation and had no such problems.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eDue to shallow gas from site survey the\r\nwell was moved 350 m away from target and drilled deviated. Wildcat well\r\n6406/12-1 S was spudded with the semi-submersible rig Ross Rig 15 December\r\n1990. A pilot hole was first drilled to 992 m where gas started to flow into\r\nthe well bore. The well was killed with heavy mud and plugged. The well was\r\nre-spudded 2 January 1991. No major problems occurred while drilling the well\r\nafter re-spudding. The pore pressure was 1.55 g/Cm3. and gas values were\r\ngenerally low and decreasing down hole. It was drilled to a total depth of 3965\r\nm in the Middle Jurassic Melke Formation. The well was drilled with sea","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"741","properties":{"OBJECTID":741,"wlbNpdidWellbore":1712,"wlbName":"25/2-14","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 25/2-14 was drilled to appraise the\r\nJurassic C prospect on the Frøy Field in the central Viking Graben. The\r\nnorthern part of the Frøy Field appears as a triangle delineated by 3 faults\r\nslightly tilted to the WNW, where the eastern limit is the main fault bordering\r\nthe Frøy structure with a 300 m down-throw, and the northern border is another\r\nmajor fault. It is the western fault trending NNW-SSE, that separates the\r\nnorthern C compartment from the rest of the field, and well 25/2-14 is located\r\nin a down flank position. The location was chosen so as not to come too close\r\nto the eastern border fault, to leave a limited up dip if any, and to get a\r\nfull Vestland sequence with the assumed oil water contact within the upper part\r\nof the section.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe main objective of the well was to\r\nexplore the Middle Jurassic sandstones, which are the main reservoir in the\r\nFrøy Field. The Lower Jurassic Statfjord sandstones was a secondary target,\r\ndepending on the results at Vestland level.\u003c/p\u003e\r\n\r\n\u003cp\u003eBoulders had been observed at 38 and 40\r\nbelow seabed within 70 metres off location, and a strong reflector at 300 m\r\nindicated shallow gas. A hydrostatic regime was expected in throughout the\r\nreservoir except for Statfjord, which could be slightly over pressured.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eAppraisal well 25/2-14 was spudded with\r\nthe semi-submersible rig West Vanguard 25 January 1991 and drilled to TD at\r\n3623 m in the Early Jurassic Statfjord Formation. Minor problems were\r\nencountered while drilling 8 1/2" pilot hole down to 473 m. Top Vestland\r\nGroup (Hugin Formation) was as found at the forecasted depth at 3135 m. Top\r\nStatfjord Formation was found at 3520.5 m (expected depth was 3537 m). Both\r\nreservoirs were found water-wet. There was a general lack of shows throughout the\r\nwell, the only show was recorded on a 1 m section of core no 4 around 3157 m.\r\nGeochemical analyses confirmed a dry well all through. FMT pressure data\r\nindicated a separate pres","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"742","properties":{"OBJECTID":742,"wlbNpdidWellbore":1713,"wlbName":"34/7-17","wlbHistory":"\r\n\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 34/7-17 is located on the Vigdis\r\nField on Tampen Spur in the Northern North Sea. It was drilled on the southern\r\nextension of the C-Plus prospect, on the eastern margin of a complete or non-truncated\r\nBrent Group sequence. Furthermore, the location is defined by the down dipping\r\ngeometry to the northwest, and the proximity to a major fault zone to the\r\nsouth. The primary purpose of the well was to test the reservoir quality and\r\nfluid contacts in the prospect. The sequence was drilled in a structural\r\nposition where a large range of oil-water contacts could be tested. A secondary\r\nobjective was to test the pressure regimes in the Jurassic sequence, including\r\npossible depletion associated with pressure communication, previously identified\r\nin the nearby Tordis Field.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 34/7-17 was spudded with the semi-submersible\r\ninstallation Treasure Saga on 25 February 1991 and drilled to TD at 3115 m in\r\nthe Late Triassic Lunde Formation. Due to leaks in the riser the 26? section\r\nwas drilled riserless while the riser was sent onshore for repairs. First\r\nreturns to the rig floor was at 897 m. From the MWD logs possible shallow gas\r\nwas interpreted at 519 - 520, 576 - 576.5 and 692 -693 m, but flow checks\r\nperformed proved negative. The well was drilled with spud mud down to 897 m,\r\nand with KCl mud from 897 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eIn the Nordland, Hordaland, Rogaland and\r\nShetland Groups, the well penetrated mainly claystones with minor sandstone\r\nintervals. Top of the Brent Group reservoir was reached at 2461 m (2458 m TVD),\r\nwhich was 38 m deeper than prognosed. The Jurassic section comprised a minor\r\ninterval of the Viking Group, and a complete section of the Middle Jurassic\r\nB","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"743","properties":{"OBJECTID":743,"wlbNpdidWellbore":1714,"wlbName":"24/9-4","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 24/9-4 is located 1 km East of the\r\nborder to British sector, on the northern outskirts of the 24/9-3 Discovery.\r\nThe main objective of the well was to test the Early Eocene Frigg Formation\r\nforming a stratigraphic play in the western part of the block, where the\r\nreservoir was interpreted to result from a submarine fan deposition. The\r\nprimary risk of the prospect was the presence of the reservoir. The prognosed\r\ngross thickness of the reservoir sequence was 230 metres with a net/gross ratio\r\nof 0.50 at the well location. No secondary targets were identified.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 24/9-4 was spudded with the\r\nsemi-submersible installation Byford Dolphin on 17 April 1991 and drilled to TD\r\nat 2208 m in the Late Paleocene Lista Formation. Here, a wiper trip was\r\nperformed. When back reaming the string stuck at 1864 m. It was not possible to\r\ncirculate since the hole had packed off. Several fishing attempts were made,\r\nbut all were unsuccessful, leaving an MWD tool and a CDR tool in the hole. The\r\nhole was then cemented to 1733 m. The sidetrack vas kicked off from 1753 m to\r\nan angle of four degrees before pulling out at 1842 m. A conventional packed\r\nhole assembly vas then run to try to drill to section TD. Drilling continued to\r\n2021m where a viper trip vas performed to ream tight hole sections. Drilling\r\nresumed without incident to 2164 m where bottoms up vas circulated before\r\ntripping out. The string became differentially stuck whilst pulling out of the\r\nhole. After spotting a pill and jarring for several hours a back-off charge vas\r\nrun leaving a 30 m fish in the hole, which included an MWD tool. Several\r\nunsuccessful fishing runs were attempted before running a VSP and E-logs. The\r\nwell vas then plugged and abandoned at 2164 m.\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 24/9-4 penetrated the top of the\r\nFrigg Formation sands at 1766 m, which was 51 metres deeper than prognosed. It\r\nconsisted of very fine to fine grained well-sorted very argillaceous sandstone\r\nstringer","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"744","properties":{"OBJECTID":744,"wlbNpdidWellbore":1715,"wlbName":"2/11-8","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 2/11-8 was designed to drill on the\r\nwestern part of block 2/11, approximately 2.3 km north of the Norwegian-Danish\r\nsector line. The well was located in the western part of the Ål Basin,\r\nseparated from the Grensen Nose to the west by a series of faults. The primary\r\ntarget was sandstone of Late Jurassic age. Pre-Late Jurassic sandstones,\r\nprobably Permian, were considered the secondary target. The main objectives for\r\nwell 2/11-8 were to prove hydrocarbons in the target Formations; to define the\r\nreservoir level and reservoir quality adjacent to the Grensen Nose; and to\r\ncollect geological information important for further reservoir evaluation and\r\ngeological modelling in the area. Seismic amplitude anomalies were present at\r\n347 m, 435 m, and 597 m. Shallow gas could not be excluded at these levels so\r\nan 8 1/2" pilot hole was planned to be drilled. The total depth of the\r\nwell was planned to be at 4616 m, in igneous rocks of Permian age.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 2/11-8 was spudded with the\r\nsemi-submersible installation Polar Pioneer on April 3 1991 and drilled to a\r\ntotal depth of 4584 m in clastic rocks of Carboniferous to possible Devonian\r\nage. The well was drilled with spud mud down to 1018 m, with ANCOQUAT cation\r\npolymer mud from 1018 m to 2515 m, with KCl mud from 2515 m to 3717 m, and with\r\nHPHT mud from 3717 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe only Late Jurassic (Ryazanian to\r\nVolgian) sediments encountered in the well were 3 m of carbonaceous claystone,\r\nrepresenting the Mandal Formation of the Tyne Group. The thin Jurassic section\r\nrested unconformably on Carboniferous sediments. Poor shows were observed in\r\nthe Jurassic claystones as well as in carbonaceous claystones between 4265 m to\r\n4335 m in the Carboniferous. A single 10 m core was cut at TD for stratigraphic\r\npurposes. The core recovered claystones with minor sandstone interbeds and\r\nstringers of limestone and was dated to possible Devonian. No fluid samples\r\nwere taken. Th","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"745","properties":{"OBJECTID":745,"wlbNpdidWellbore":1717,"wlbName":"30/9-12","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well 30/9-12 is located on the\r\nsouthern part of the Alpha and Gamma structure in the Oseberg Sør area, some 4\r\nkm south of well 30/9-2, and approximately 100 m to the south of the licence\r\nboundary PL 079/104. The main target of the well was to appraise the southern\r\nextension of the Oseberg field, i.e. to improve the seismic mapping of the\r\nAlpha South/Gamma structural complex; to improve stratigraphical mapping and\r\ncontrol of the hydrocarbon bearing Brent Group in the area; to test an\r\noil/water contact in relation to the Oseberg Field and the C-structure; and to\r\ntest communication relations in the Oseberg Field.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eAppraisal well 30/9-12 was spudded with\r\nthe semi-submersible installation Vildkat Explorer on the 7 April 1991 and\r\ndrilled to TD at 2994 m in the Cook Formation of the Dunlin Group. The well was\r\ndrilled with spud mud to 1016 m and with KCl polymer mud from 1016 m to TD.\r\nShallow gas predicted at 184 m proved to be the base of a boulder zone, probably\r\na glacially eroded horizon.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well proved a column of 10.3 m of\r\nmoveable hydrocarbons oil in the Tarbert Formation with an oil down-to contact\r\nat 2674.5 m, However, as no oil/water contact was established, uncertainty\r\nremained as to the amount of hydrocarbon resources within the southern part of\r\nthe Alpha South structure. A total of 70.4 m of net sand was calculated for the\r\nBrent sequence, with an average porosity of 21.5% and calculated average Sw of\r\n26.1% in the Tarbert Formation.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe pressure data obtained from the well\r\nindicated a significant depletion caused by production from Oseberg B.\u003c/p\u003e\r\n\r\n\u003cp\u003eGood oil shows were recorded on cuttings\r\nfrom limestone stringers in the interval 2325 m to 2554 m in the Cretaceous and\r\non sandstones (conventional and sidewall cores) in the interval 2658 m to 2673\r\nm in the Tarbert Formation. A total of 10 conventional cores were cut, one in\r\nthe Heather Formation and nine through the entire Brent sequ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"746","properties":{"OBJECTID":746,"wlbNpdidWellbore":1719,"wlbName":"34/8-5","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 34/8-5 is located on the A-structure\r\non the Visund Field. This is a NNE-SSW oriented elongated fault block with the\r\nPre-Cretaceous strata dipping towards WNW. The A-Central fault divides the\r\nA-structure into the A-North and A-South compartments. Well 34/8-5 was drilled on\r\nthe southern part of the A-South compartment, ca 6 kilometres SSW of Visund\r\nDiscovery well 34/8-1. The primary objective was to appraise the Jurassic Brent\r\nGroup. A secondary objective was to test reservoir quality of an Oligocene\r\nsubmarine fan system. Possible shallow gas was predicted at 604 and 793 m.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 34/8-5 was spudded with\r\nthe semi-submersible installation Transocean 8 on 18 February 1991 and drilled\r\nto TD at 3540 m (3528 m TVD) in the Late Triassic Lunde Formation. The 36"\r\nhole was drilled to TD at 406 m, but when attempting to stab in the 30"\r\ncasing the hole could not be located. The well was re-spudded and this time\r\nwith success. An 8 1/2" pilot hole was drilled from 406 m to 850 m to\r\ncheck for shallow gas. No gas was observed. The well was planned vertical, but\r\nbuilt some angle below 2660 m, and at ca 2720 m the deviation was ca 10 deg.\r\nThis angle kept down to TD resulting in a 12 m discrepancy between measured and\r\nvertical depth at TD. There were also some hole curable problems during logging,\r\nbut otherwise operations proceeded without significant problems. The well was\r\ndrilled with seawater and hi-vis pills down to 1197 m and with KCl/polymer mud\r\nfrom 1197 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThinly developed water bearing Oligocene\r\nand Eocene sands were encountered. The Brent Group was encountered at 2855 m\r\nand was found water bearing with oil shows on the cores. The shows continued\r\ndown to 2977 m. Otherwise there w","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"747","properties":{"OBJECTID":747,"wlbNpdidWellbore":1727,"wlbName":"1/9-4 R","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 1/9-4 R is a re-entry of well 1/9-4\r\nin the Central Graben of the North Sea. The purpose of the re-entry was\r\npermanent abandonment. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell was entered with the\r\nsemi-submersible installation Ross Rig on 21 April 1991. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well head was removed from the sea\r\nfloor.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was permanently abandoned on 26\r\nApril.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eTesting\u003c/span\u003e\u003c/b\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo drill stem test was performed.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"748","properties":{"OBJECTID":748,"wlbNpdidWellbore":1732,"wlbName":"6608/10-3","wlbHistory":"\u003cb\u003e\r\nGeneral\r\n\u003c/b\u003e\r\n\u003cp\u003e\r\nThe main objective of well 6608/10-3 was to appraise oil accumulation in the Jurassic Fangst and Båt groups in the Northern Fault Block on the Norne field off shore Mid Norway. \r\n\u003c/p\u003e\r\n\u003cb\u003e\r\nOperations and results\r\n\u003c/b\u003e\r\n\u003cp\u003e\r\nAppraisal well 6608/10-3 was spudded by the semi-submersible installation \"Ross Rig\" on 7 January 1993 and drilled to a total depth of 2921 m, into rocks of Lower Jurassic age. The well was drilled water based. Seawater/bentonite spud mud was used down to 469 m, seawater/CMC EHV spud mud from 469 m to 874 m, and Gyp/PAC polymer mud from 874 m to TD.\r\nOil and gas was encountered in the Early to Middle Jurassic Båt and Fangst Groups. Eleven cores were cut in the interval 2560 m to 2765 m, from the lower part of the Melke Formation, through the Fangst Group and into the Tilje Formation of the Båt Group. Four segregated FMT samples were taken at 2599.2 m in the Garn Formation (gas, mud filtrate, and small amount of oil), 2603.2 m in the Garn Formation (mud filtrate, gas, and oil), 2624.5 m in the Ile Formation (gas, and oil), and at 2715.2 in the Tilje Formation (mud filtrate and water with small amount of gas).\r\nThe well was suspended on 11 March as an oil and gas appraisal well. The well was re-entered on 8 August 1995 with the semi-submersible installation \"Ross Isle\". The re-entry, 6608/10-3 R, was permanently plugged and abandoned as an oil and gas appraisal well.\r\n\u003c/p\u003e\r\n\u003cb\u003e\r\nTesting\r\n\u003c/b\u003e\r\n\u003cp\u003e \r\nOne drill stem test was performed in well 6608/10-3 in the Ile Formation (perforated interval 2617-2648 m). The well produced 1250 Sm3/D of oil with a density of 860 kg/m3 at standard conditions and 102500 Sm3/D of gas with a relative density of 0.65 (air=1.0) through a 60/64\" (23.44 mm) choke.\r\n\u003c/p\u003e\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"749","properties":{"OBJECTID":749,"wlbNpdidWellbore":1747,"wlbName":"34/10-34","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 34/10-34 was designed to drill the\r\nC6 structure west of the Gullfaks Field. Block 34/10 is situated in the Tampen\r\nSpur area and the 6C structure is an elongated, lens shaped rotated fault block\r\ndipping to the NW and bounded to the East and South by faults. At the well\r\nlocation the Heather Formation and uppermost Tarbert Formation have been\r\neroded. The main objective of the well was to test the potential for\r\nhydrocarbons in the Brent Group sands west of the Gullfaks Field. No secondary\r\nprospects were defined.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 34/10-34 was spudded with\r\nthe semi-submersible installation Deepsea Bergen on 10 April 1991 and drilled\r\nto TD at 2410 m in the Early Jurassic Cook Formation. While drilling the\r\n26" hole some indications of gas was detected on ROV sonar, but no gas was\r\nobserved during hole opening. Apart from some problems with stuck pipe,\r\ndrilling went without significant problems. The screen from the drill string\r\ndropped into the MWD tool, thus preventing pulses from arriving at the surface.\r\nDue to this MWD is missing from 1349 m to1675 m. The well was drilled with\r\ngel/CMC down to 795 m, with gypsum/PAC from 795 m to 1994 m, and with\r\nbentonite/Lignite from 1994 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eSpotted shows were observed in limestones\r\nin the interval 1558 m to 1678 m in the Hordaland Group, through the Balder\r\nFormation and into the upper part of the Lista Formation. The Viking Group was\r\nencountered at 1991 m and consisted of only two m of Heather Formation. The\r\nTarbert Formation sandstones was encountered at 1993 m and proved oil. From\r\nelectric logs and FMT pressure measurements the OWC was interpreted at 2013.5\r\nm, with continuous oil shows on cores extending down to 2040 m. A weak oil show\r\nwas observed in an SWC from the top of the Cook Formation sandstone at 2360 m.\r\nOne segregated sample was taken at 2006.0 m. The sampling time for the 2-3/4\r\ngallon chamber was 62.3 minutes and for the one-gallon chamber 34.8 ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"750","properties":{"OBJECTID":750,"wlbNpdidWellbore":1749,"wlbName":"6507/8-5","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 6507/8-5 was designed to drill the\r\nOmega prospect, a horst, located east of the Heidrun Field. Structurally the\r\narea is situated on the Sør High with the Halten Terrace to the southwest and\r\nthe Trøndelag Platform to the East. The Omega horst had only a minor structural\r\nclosure of 10-20 m, but assuming scaling capacity of a fault, a stratigraphic\r\nclosure would exist both up-dip and further down-dip of the structural closure.\r\nThe fault was prognosed with a maximum throw of 140 m on top Ror Formation\r\nlevel. The main objective of the well was to test the hydrocarbon and reservoir\r\n-potential of sandstones of the Middle/Early Jurassic Fangst Group supposed to\r\nbe present on the downthrown eastern side of the fault. None of the nearby\r\ncorrelation wells penetrated highly over pressured formations. Shallow gas\r\nwarnings were given for three levels in the interval 518 to 960 m.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 6507/8-5 was spudded with\r\nthe semi-submersible installation Ross Rig on 3 March 1991 and drilled to TD at\r\n2000 m MD in the Early Jurassic Tilje Formation. The well was drilled in 13\r\ndays without major problems. However, while drilling 9 7/8" pilot hole at\r\n854 m shallow gas was encountered. The well was plugged back and a 13 3/8"\r\ncasing was set above the gas. The well was drilled with seawater and hi-vis\r\npills down to 818 m and with Gyp/PAC mud from 818 m to TD. \u003c/p\u003e\r\n\r\n\u003cp\u003eSix meter of the Late Cretaceous Shetland\r\nGroup was encountered at 1781 m; otherwise the Cretaceous section was absent in\r\nthe well. Three meter of Spekk was penetrated at 1787 m. It was described as\r\nsilty carbonaceous claystone with traces of coal fragments. The potential\r\nreservoir sands of the Fangst and Båt Groups were penetrated but proved not to\r\nbe hydrocarbon bearing. No shows were recorded in any section of the well, not\r\neven in the claystone of the Spekk Formation. One conventional core was cut in\r\nthe interval 1856.7 m to 1884.5 m in the Not/Ile","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"751","properties":{"OBJECTID":751,"wlbNpdidWellbore":1754,"wlbName":"6506/11-2","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 6506/11-2 was drilled on the\r\nsouthwestern extension of the Smørbukk Field on the Halten Terrace. The\r\nexploratory objectives of the well were to prove oil in the Tilje, Ile, and\r\npossibly Garn Formations in the southwestern part of the Smørbukk Discovery.\r\nThe well would also provide essential field development data for this part of\r\nthe Smørbukk Discovery in connection with the Smørbukk South Field development\r\nplanning.\u003c/p\u003e\r\n\r\n\u003cp\u003eShallow gas warnings were given for seven\r\nlevels down to 910 m. Maximum pore pressure was expected to ca 1.60 g/cm3 when\r\nentering the Late Jurassic reservoir.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 6506/11-2 was spudded with the\r\nsemi-submersible installation Ross Rig on 8 May 1991 and drilled to TD at 4813\r\nm in the Early Jurassic Åre Formation. No shallow gas was encountered. The well\r\nwas drilled with seawater and hi-vis pills down to 830 m and with\r\ngypsum/polymer mud from 830 m to 2307 m. When running the 13 3/8" casing\r\nit got stuck. Several Imcospot/Pipelax pills were spotted to free the pipe, but\r\nwithout success, so the hole was plugged back and sidetracked. The sidetrack\r\nfrom 1257 m was drilled with gypsum/polymer mud down to 2255 m, with\r\ngypsum/PAC/Kemseal polymer mud from 2255 m to 4238 m, and with\r\nbentonite/Thermopol/Ancotemp mud from 4238 m to TD. Planned time budget for the\r\nwell was 74 days, without testing. The well took 172 days. Significant time was\r\nlost due to the stuck 13 3/8" casing with subsequent sidetrack drilling.\r\nProblems during DST 1 and P&A phase also contributed significant lost time.\r\nHowever, the main deviation from planned time consumption reflected operational\r\ndecisions during drilling. Extended logging and coring programs were approved\r\nin the course of making hole. The results also lead to confirmation of extended\r\ntesting. \u003c/p\u003e\r\n\r\n\u003cp\u003eMaximum pore pressure, 1.71 g/cm3, was\r\nseen in the top of the Shetland Group at ca 2400 m. The pore pressure in the\r\nLate Jurassic was 1.66 g/cm","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"752","properties":{"OBJECTID":752,"wlbNpdidWellbore":1756,"wlbName":"2/7-26 S","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 2/7 26 S is located on the Embla\r\nField in the Central Graben of the North Sea. It was designed to test the pre-Jurassic\r\nsandstones, which had shown commercial quantities of hydrocarbons in the 2/7-20,\r\n2/7-21 S, and 2/7-23 S wells. The objective of the well was to confirm the\r\npresence of hydrocarbon bearing sandstones in the western fault block of the\r\nstructure and to establish the productivity of this reservoir section through a\r\nprogram of well testing and coring. Well location and TD was chosen so that\r\nboth the upper and lower sandstone members of the pre-Jurassic sequence would be\r\npenetrated. The target location was 300 m to the south of the 2/7-9 well at\r\nBase Cretaceous level. The reservoir section was expected to be highly\r\nfractured and over-pressured. Shallow gas was expected since gas had been\r\nencountered in all wells drilled from the template location over the 2/7-20\r\nwell. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eAppraisal well 2/7 26 S was spudded with\r\nthe semi-submersible installation West Delta on 20 March 1991 and drilled to TD\r\nat 4848 in Devonian rocks. The well was drilled deviated from a template\r\nlocated over the 2/7-20 well to penetrate the target reservoir section in the\r\nwestern fault block of the Embla structure. Minor shallow gas was detected in\r\nsandy zones with an increase in background gas from 4 to 64 units. Apart from\r\nsome failures when logging and some stuck pipe experiences, drilling proceeded\r\nwithout significant problems. The well was drilled with seawater and hi-vis\r\nsweeps down to 575 m, with KCl/PAC mud from 575 m to 4125.5 m, and with Enviromul\r\noil based mud from 4125.5 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe 9 5/8" casing was set in\r\nclaystones of the Lower Cretaceous, Rødby Formation. The remaining Lower\r\nCretaceous section including Sola, Tuxen and Åsgård Formations was penetrated,\r\nfollowed by a Late Jurassic sequence consisting of 3 m Mandal Formation and 82\r\nm Farsund Formation. The top of the reservoir sands were encountere","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"753","properties":{"OBJECTID":753,"wlbNpdidWellbore":1759,"wlbName":"3/7-5","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 3/7-5 was drilled on the Lemen\r\nstructure, a fault bounded, salt induced trap located in the centre of the Søgne\r\nBasin in the North Sea. The Primary objective of the well was to test sandstones\r\nof the Sandnes and Bryne Formations. Secondary objectives were to evaluate the\r\nprospectivity of other possible reservoir levels (Late Cretaceous Chalk and\r\nPaleocene sandstones) within structural closure and thereby evaluate the charge\r\npotential of the local Søgne Basin hydrocarbon kitchen.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 3/7-5 was spudded with the\r\nsemi-submersible installation Dyvi Stena on 6 December 1991 and drilled to TD\r\nat 3666 m (3637.8 m TVD) in the Late Permian Zechstein Group. The well was\r\ndrilled efficiently, but some problems with deviation and logging was\r\nencountered. The hole was practically vertical down to TD in the 12 1/4"\r\nsection at 3085. The 8 1/2" section was however drilled with close to 20\r\ndeg deviation all through to TD, leading to ca 27 m difference between measured\r\nand true vertical depth at final TD. Due to hole problems no wire line logs\r\nwere run between 2198 m and 3085 m in the 12 1/4" section. The 8 1/2"\r\nsection was eventually logged to 3575 m, 90 m above final TD, but only after\r\nseveral logging attempts and a check trip. The well was drilled with spud mud\r\nand viscous pills down to 610 m, and with seawater/gypsum/polymer mud from 610\r\nm to TD. \u003c/p\u003e\r\n\r\n\u003cp\u003eAbove the objective Sandnes / Bryne\r\nformations there were no evidence of producible hydrocarbons, although it\r\nshould be stated that this could not be completely confirmed by logs because a\r\nsignificant section could not be logged with wire line logs. Top Sandnes\r\nFormation was encountered at 3379 m and top Bryne Formation at 3436 m. FMT\r\npressure plot indicated a water gradient throughout the Sandnes / Bryne reservoir.\r\nPetrophysical evaluation gave no indications of hydrocarbons in the cleaner\r\nparts of the reservoir but, there was some indi","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"754","properties":{"OBJECTID":754,"wlbNpdidWellbore":1762,"wlbName":"15/5-4","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 15/5 4 was drilled on a structure\r\nthat straddles the border between the U.K. and the Norwegian sector of the\r\nNorth Sea. Hydrocarbons were proven in the structure by three earlier wells\r\ndrilled in the UK sector (U.K. 16/13a-3, 16/13a-4, and 16/13a-5). Well 16/13a-4\r\npenetrated a gas cap at the top of the structure and an oil column down to base\r\nreservoir. The other two wells penetrated an oil zone and a water leg. The\r\nobjective of well 15/5-4 was to assess the extension of hydrocarbon bearing\r\nSele Formation sand towards the east into PL048. The well position was chosen for\r\npossible use as a producer in the event of a positive appraisal. Prognosed\r\ntotal depth was 2300 m. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 15/5-4 was spudded by the\r\nsemi submersible installation Vildkat Explorer on 6 June 1991 and drilled to TD\r\nat 2300 m in rocks of the Paleocene Heimdal Formation. No shallow gas was\r\nobserved on the predicted sand/gas levels. Drilling proceeded without any\r\nsignificant problems. The well was drilled with spud mud down to 1027 m and\r\nwith KCl/polymer mud from 1027 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThin sands of the Sele Formation were\r\nencountered at 2120 m and had good oil shows. The reservoir thickness was\r\ncalculated to 7.5 m. The sandstones of the Heimdal Formation were penetrated\r\nbelow the oil/water contact and were totally water wet. Weak oil shows was\r\ndescribed on sidewall cores from claystone at 1909 m in the Frigg Formation and\r\nsandstone at 2182 m in the Lista Formation.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eA total of six cores were cut from 2106 m\r\nto 2147 m over the reservoir section. RFT fluid samples were attempted at 2125.1\r\nm, 2125.3 m, 2125.8 m, and 2129.5 m. Sampling suffered from sand plugging and\r\nonly the samples from ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"755","properties":{"OBJECTID":755,"wlbNpdidWellbore":1767,"wlbName":"16/10-2","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eBlock 16/10 is located in a structurally\r\ncomplex area between the Viking Graben, the Central Graben, the Witch Ground\r\nGraben and the Ling Graben.\u00A0 Well 16/10-2 is the second well drilled in block\r\n16/10 PL 101 operated by Norsk Agip; the first one 16/10-1 was drilled May-July\r\n1986. The purpose of the well was to test the hydrocarbon potential of the\r\n"Delta" structure located in the west part of 16/10 block. This\r\nstructure is a tilted fault block elongated north-south bounded to the west by\r\na north-south trending normal fault, and dip-closing to the north, east and\r\nsouth. It was interpreted as the largest structure in block 16/10 in terms of\r\npossible oil reserves. The structure is not salt-induced and being one of the\r\noldest in this area it was also considered prospective for possible early\r\nmigration. The Upper Jurassic and the Lower Cretaceous shales constituted the\r\nseal rocks for the geological model. The main and the secondary targets were\r\nrespectively the "Oxfordian Sandstones" (Upper Jurassic) and the\r\nTriassic sandstones of the Skagerrak Formation that had been found hydrocarbon\r\nbearing in the nearby blocks in wells 6/3-1, 15/12-5, 15/12-4, 15/12-8, 15/12-6\r\nand 16/7-4.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eExploration well 16/10-2 was spudded with\r\nthe semi-submersible installation Byford Dolphin on 20 June 1991 and drilled to\r\na total depth of 3150 m in the Triassic sandstones of the Skagerrak Formation.\r\nThe well was drilled with seawater and gel down to 417 m, with Seawater and\r\ngypsum polymer from 417 m to 2798 m and with Bentonite/Anco Temp mud from 2798\r\nm to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe Quaternary/Tertiary sequence\r\nconstituted predominantly marine claystones of the Nordland, Hordaland and\r\nRogaland Groups. The Cretaceous sequence was mainly represented by limestones of\r\nthe Chalk Group and by the reddish claystones and calcareous marls of the\r\nCromer Knoll Group that overlay the Base Cretaceous Unconformity found at 2818\r\nm. The Upper J","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"756","properties":{"OBJECTID":756,"wlbNpdidWellbore":1768,"wlbName":"15/9-17 R","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 15/9-17 R is a re-entry of well\r\n15/9-17 on the Sleipner Terrace in the Viking Graben of the North Sea. The purpose\r\nof the re-entry was plugging and permanent abandonment.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 15/9-17 was re-entered with the semi-submersible\r\ninstallation Ross Rig on 28 April 1991.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo significant problem was encountered in\r\nthe operations. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was plugged and permanently\r\nabandoned on 4 May 1991.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eTesting\u003c/span\u003e\u003c/b\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo drill stem test was performed. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"757","properties":{"OBJECTID":757,"wlbNpdidWellbore":1770,"wlbName":"30/9-12 A","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 30/9-12 A was designed as a\r\nsidetrack from well 30/9-12 on the Alpha South structure on the southern\r\nextension of the Oseberg Field. Well 30/9-12 proved a 10 m column of oil in the\r\nTarbert Formation, but as no oil/water contact was established there remained\r\nuncertainty as to the amount of hydrocarbon resources within the southern part\r\nof the Alpha South structure. The objectives of well 30/9-12A were to sidetrack\r\napproximately 700 m down dip south-eastwards in order to establish the water\r\npressure and oil/water contact in the Tarbert Formation in the area as well as\r\nto verify the structural mapping and geological model of the area. No drilling\r\nhazards were anticipated. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eAppraisal well 30/9-12 A was with kicked\r\noff with the semi-submersible rig Vildkat Explorer on 9 May 1991. Kick-off\r\npoint was at 1033 m, below the 13 3/8" casing shoe in well 30/9-12. The\r\nwell bore was drilled to a total depth of 3061 m (2927 m TVD RKB) in the Drake\r\nFormation of the Dunlin Group. It was drilled with KCl polymer mud from\r\nkick-off to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well encountered an unexpected\r\nHeather Formation sandstone development that proved to be hydrocarbon bearing.\r\nA total of 2.63 m net pay sand was calculated, with an average porosity of 23.3%\r\nand average water saturation of\u003c/p\u003e\r\n\r\n\u003cp\u003e31.4%. Sandstones of the Brent Group were\r\npenetrated below the regional oil/water contact and were found to be totally\r\nwater bearing. A total of six conventional cores were cut in this well in the\r\ninterval 2874 m to 2919 m in the Tarbert and Ness Formations. A total of 30\r\nsidewall cores were attempted and 28 were recovered. Drilling went on without\r\nany significant problems to TD. Oil was recovered from RFT samples taken at\r\n2776.3 m and 2776.6 m. Geochemical analyses showed the Heather oil in 30/9-12 A\r\ncorrelate very well with Tarbert oils from 30/9-12 and 30/9-10, indicating a\r\ncommon source and identical maturity.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was suspen","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"758","properties":{"OBJECTID":758,"wlbNpdidWellbore":1778,"wlbName":"15/12-8","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 15/12-8 was drilled ca 3.5\r\nkm east of the 15/12-4 well, which made the Varg oil discovery in Jurassic and\r\nTriassic sandstones. The main objective of the well was to test the potential\r\nfor hydrocarbons in sandstones of Oxfordian and Triassic age. Seismic anomalies\r\nat 437, 467, 479 and 803 m indicated possibility for shallow gas. Planned TD\r\nfor the well was 3260 m.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 15/12-8 was spudded with the\r\nsemi-submersible installation Deepsea Bergen on 5 June 1991 and drilled to TD at 3054 m in the Triassic Skagerrak Formation. No significant problems occurred\r\nduring operations. The well was drilled with seawater / hi-vis pills / CMC down\r\nto 615 m, with KCl/polymer mud from 615 m to 2855 m, and with Ancotemp/bentonite\r\nmud from 2855 m to TD. No shallow gas was encountered.\u003c/p\u003e\r\n\r\n\u003cp\u003eJurassic Vestland Group sandstone was\r\nencountered hydrocarbon-bearing at 2838 m. The hydrocarbon column extended 23 m\r\ninto Triassic sandstone of the Skagerrak Formation. The gas/water contact was\r\nestimated to 2877 m, confirmed by FMT pressure gradients and wire line logs. The\r\nwell was tested, and since no core was cut through the reservoir, the well was\r\nsidetracked at 2623 m with TD at 2940 m. The sidetrack was drilled with\r\nAncotemp/bentonite mud. Three conventional cores were cut in the interval 2841\r\n- 2902 m. The sidetrack was formally named 15/12-8 A.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe FMT tool was run in well 15/12-8 and\r\n15/12-8A. One segregated sample was taken at 2863 m in 15/12-8 (gas, condensate\r\nand mud filtrate) and another in the water zone at 2888 m in well 15/12-8 A (recovered\r\nmud only due to seal failure). \u003c/p\u003e\r\n\r\n\u003cp\u003eWell 15/12-8 was permanently abandoned on\r\n 14 July 1991 as a gas/condensate discovery. The 15/12-8 A sidetrack was\r\npermanently abandoned on 29 July as a gas/condensate appraisal well.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eOne DST test was performed in 15/12-8 in\r\nthe interval 2838 - 2869 m. The well produced gas-condensate with a de","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"759","properties":{"OBJECTID":759,"wlbNpdidWellbore":1780,"wlbName":"35/11-5","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 35/11-5 was drilled on the\r\n"D" West prospect on the northwestern part of the Horda Platform, and\r\nca 18 km north of the Troll Field. The primary objective for 35/11-5 was the\r\nMiddle Jurassic Brent Group. Reservoirs were expected in the Tarbert, Ness,\r\nEtive, and Oseberg Formations. Secondary there was a possibility for reservoir\r\ndevelopment in the Late Jurassic Sognefjord Formation. Similar sands are the\r\nmain reservoir in the Troll area, and were expected to be well developed in the\r\neastern part of the block. No shallow gas warnings were given. Boulders might\r\nbe encountered in the interval 395 - 532 m. The well was planned to be drilled\r\nto a total depth of 3678 m.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 35/11-5 was spudded with the\r\nsemi-submersible installation Sovereign Explorer on 27 June 1991 and drilled to\r\nTD at 3769 m in the Early Jurassic Statfjord Formation. The well reached a\r\ndepth of 1118 m before technical problems caused the well to be plugged back\r\nand sidetracked. Further problems in the sidetrack caused the well to be\r\nabandoned and re-spudded on 18 July 1991, 50 m northwest of the original\r\nlocation. The first well bore was drilled with seawater and hi-vis pills. The\r\nsecond and final well bore was drilled with seawater and hi-vis pills to 1010\r\nm, and with KCl/polymer mud from 1010 m to TD \u003c/p\u003e\r\n\r\n\u003cp\u003eWater bearing sandstones were drilled in\r\nPalaeocene. The Draupne Formation was penetrated at 2657.5 m. The Sognefjord\r\nFormation came in at 2875 m and consisted predominantly of claystones with some\r\nsandstone interbeds. Shows were observed in cuttings, and RFT samples recovered\r\ncontained oil and gas. However, reservoir quality of the sandstones was\r\ngenerally poor and there was less than 5 m of net pay. In the Middle Jurassic\r\nBrent Group, shows were observed in cores from 3208 m down to 3305 m. Light\r\noil/condensate and gas was recovered from an RFT sample taken at 3214 m.\r\nReservoir quality was however poor with only 5.","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"760","properties":{"OBJECTID":760,"wlbNpdidWellbore":1782,"wlbName":"6608/10-2","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 6608/10-2 is located on the Dønna\r\nTerrace offshore Mid Norway. The primary objective of the well was to test the hydrocarbon\r\npotential in the Middle Jurassic Fangst Group sandstones. Possible sandy\r\nequivalent to the Rogn Formation in the Viking Group was a secondary objective.\r\nThe well was planned with TD at 3225 m with a commitment to drill into rocks of\r\nTriassic age.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 6608/10-2 was spudded with\r\nthe semi-submersible installation Ross Rig on 28 October 1991 and drilled to TD at 3678 m in Late Triassic rocks of the Åre Formation. Some problems with\r\ntight hole were experienced between 1800 and 2300 m in the 12 1/4"\r\nsection. Due to presence of hydrocarbons and the commitment to drill to\r\nTriassic the well was extended both in time and depth compared to programme. Technical\r\noperations went smoothly with little down-time. The well was drilled with\r\nseawater and hi-vis pills down to 874 m, with gypsum/PAC mud from 874 m to 2576\r\nm, and with Ancotemp/bentonite mud from 2576 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eShows were observed in limestone in the interval\r\n2160 ? 2271 m in the Cretaceous Nise and Lyr Formations. Oil and gas were\r\nencountered in the Båt and Fangst Groups (Lower- Middle Jurassic). From FMT\r\ndata and electric logs the gas-oil contact was interpreted at 2605 m, and the\r\noil-water contact at 2713.5 m. The Rogn Formation equivalent was not present in\r\nthe well.\u003c/p\u003e\r\n\r\n\u003cp\u003eA total of 141.5 m core was recovered in\r\nsix cores from the interval 2590 ? 2741 m in the Fangst and Båt Groups. Two FMT\r\nwire line samples were collected; a gas sample at 2583.2 m and an oil sample at\r\n2650.5 m.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 29 January 1992 as an oil and gas discovery.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eFour intervals were perforated and\r\ntested.\u003c/p\u003e\r\n\r\n\u003cp\u003eDST 1 tested the interval 2715 ? 2720 m\r\nin the in the lower Tofte Formation. The test produced 310 Sm3 water /day\r\nthrough a 2" choke. Maximum bottom hole","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"761","properties":{"OBJECTID":761,"wlbNpdidWellbore":1787,"wlbName":"7/12-11","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 7/12-11 was designed to test\r\n7/12-JU6 prospect, a Late Jurassic Ula Formation sand in a structural prospect\r\nsome 7 km east of the Ula Field. Well 7/12-11 was located close to the edge of\r\nthe perceived Late Jurassic Ula Trend fairway.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe prospect was defined as a structural\r\ntrap with fault closure to the east and north, and dip closure to the\r\nsouthwest. Lateral seal to the east was thought to be provided by cross-fault\r\nseal of Late Jurassic reservoir against Triassic shales and siltstones. The key\r\nelement of risk was trap effectiveness, as the prospect relied on a shattered\r\nsub-seismic fault zone in the northeastern corner. The results might have\r\nimplications for further prospectivity in the licence.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe primary objective for the 7/12-11\r\nwell was to prove a volume of oil that was commercial as a tieback development\r\nto the Ula Platform. Secondary objectives were the uppermost part of the\r\nTriassic rocks and the Middle Jurassic Bryne Formation.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 7/12-11 was spudded with the\r\nsemi-submersible installation Ross Isle on 31 August 1991 and drilled to TD at\r\n3865 m in the Triassic Skagerrak Formation. A 9 7/8" pilot hole was\r\ndrilled to 950 m, and some shallow gas was detected by ROV sonar and observation\r\nof some surface bubbles at 518 m. The 17 1/2" hole was drilled with the\r\nexperimental mud system RCS/DF+. In the 12 1/4" hole this mud was\r\ngradually diluted and displaced to a KCl/IOBOND mud. Drilling proceeded without\r\nsignificant problems to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe Ula sandstones came in at 3787.5 m,\r\n39.5 m deeper than prognosed. It was only 12.5 m thick which was 78 m thinner\r\nthan prognosed. The Bryne Formation was absent. Very weak hydrocarbon\r\nfluorescence was observed in sand stringers of the Lista Formation. Minor gas\r\nshows were observed in the Mandal Formation. Occasional oil stained grains with\r\nvery weak cut fluorescence were seen in the cuttings of the Ula Formation.","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"762","properties":{"OBJECTID":762,"wlbNpdidWellbore":1789,"wlbName":"6607/5-2","wlbHistory":"\u003cp\u003eWell 6607/5-2 was designed to drill the Amundsen II prospect on\r\nthe NE-SW trending Bodø High. Block 6507/5 is located in the NW corner of the\r\nNordland II, which is a geological province separated from the Halten and Dønna\r\nTerrace by the deep Træna Basin to the east. The main objective of the well was\r\nto test the hydrocarbon potential of the Middle-Lower Jurassic shallow marine\r\nsandstones. The prognosed formation pressure was supposed to follow the general\r\nbehavior of the Haltenbanken Region, where a pressure regression might be\r\nexperienced towards the Base Cretaceous at 4080 m. The objective Middle\r\nJurassic sandstones were expected to exhibit a potentially high level of\r\noverpressure. No shallow gas warnings were given. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 6607/5-2 was spudded on 7\r\nAugust 1991 by the semi-submersible installation "Dyvi Stena" and\r\ncompleted 16 November 1991 at a total depth of 4684 m in intrusive rocks within\r\nthe Upper Cretaceous Kvitnos Formation. Bentonite mud was used to 1225 m, water\r\nbased KCl polymer mud was used from 1225 m to TD. There were no lost time\r\naccidents. The 523 m of water depth made this well the deepest well to date\r\ndrilled on the Norwegian continental shelf. The well bore was maintained in\r\nexcellent conditions over the entire well. Only 0.9 day of hole instability NPT\r\nwas accumulated for this well. Throughout the well, immediate mud weight\r\nincrease was made to counter excessive drag thus contributing to hole\r\nstability. During logging at TD, RFT results indicated a maximum pore pressure\r\nof 1.51 g/cm3. Following open hole logging of the 8 1/2" section, on\r\nrequest, the hole was plugged back and sidetracked at 3998 m RKB to permit a\r\ncore cutting from 4161 - 4188.5 m in the Nise Formation sand, prior to resuming\r\nplug and abandon. No fluid samples were taken. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe well did not penetrate the primary\r\nobjective of Middle-Early Jurassic sandstones. The seismic reflectors\r\ninterpreted as Jurassic turned out to b","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"763","properties":{"OBJECTID":763,"wlbNpdidWellbore":1792,"wlbName":"2/4-17","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThe Exploration well 2/4-17 was drilled\r\non the NW Tor prospect situated in the Production License 018. The objective\r\nwas to test the Late Jurassic and Early Permian sections in a rotated fault\r\nblock on a terrace NW of the Tor Field. The block is situated in the Central\r\nTrough, which is part of the failed Mesozoic North Sea, rift system. The\r\nCentral Trough comprises a complex series of narrow discontinuous highs and\r\nlows with a NW-SE trend. The most important basins are the Feda Graben, the Breiflab Basin and the Søgne Basin. From the Feda Graben/Breiflab Basin up to the Sørvestlandet\r\nHigh several rotated fault blocks form platforms and small highs, named the Cod\r\nTerrace, the Hitra High and the Steinbit Terrace. The NW Tor Prospect is\r\nsituated on a Terrace between the Hitra High and the Feda Graben.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well was spudded with the 3-leg\r\njack up installation on 29 February 1992 and drilled to TD at 5258 m in the\r\nEarly Permian Rotliegendes Group. Drilling went without problems to 2081m were\r\nthe well was sidetracked because the string became stuck while taking a survey.\r\nWhile pulling out of the hole, following the cutting core to a depth of 4357.1\r\nm, an influx of gas occurred and the well was shut in. Following a 22 hours\r\nwell kill operation, the well was brought back under control. A second\r\ntechnical sidetrack was taken at 4724 m due to a twist-off of the bottom hole\r\nassembly. The well was drilled with seawater/gel down to 466 m, with KCl mud\r\nfrom 466 m to 2146 m, with Soltex from 2146 m to 2582 m, with Soltex/Drispac\r\nfrom 2582 m to 4151 m, with HTHP mud from 4151 m to 4724 m, and with High Temp\r\nmud from 4724 m to TD\u003c/p\u003e\r\n\r\n\u003cp\u003eTo thin hydrocarbon-bearing intervals\r\nwere present in the Hod Formation. At 4340 m a major hydrocarbon bearing sand\r\nof the Late Jurassic Ula Formation was encountered. At 4520 to 5027 m an\r\nexcellent quality aeolian dune sand of Early Permian age (Rotliegendes Group)\r\nwas penetrated. The overa","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"764","properties":{"OBJECTID":764,"wlbNpdidWellbore":1794,"wlbName":"36/7-1","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 36/7-1 is located on the Måløy\r\nslope, ca 4 km SE of the 35/9-1 Gjøa Discovery well. It was the third\r\nexploration well to be drilled in the licence area and tested the hydrocarbon\r\npotential of the A-East structure. The primary target was the transgressive\r\nsands of the Sognefjord and Fensfjord formations. Brent Group sandstone was\r\nsecondary target.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 36/7-1 was spudded with the\r\nsemi-submersible installation West Vanguard on 31 March 1996 and drilled to TD\r\nat 2841 m in basement rock. No significant technical problems were encountered\r\nin the operations. The well was drilled with seawater and hi-vis sweeps (spud\r\nmud) mud down to 1256 m and with ANCO 2000 mud from 1256 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well discovered oil and gas in Intra Draupne sandstones and the\r\nSognefjord Formations of Late Jurassic age as well as in middle jurassic Fensfjord Formation. The Brent Group was\r\ndry. The reservoir consists of sandstone, siltstone and shale. The free oil and\r\nfree water levels were clearly defined from the MDT pressure data and were consistent\r\nwith the fluid contacts apparent from the logs. The FOL was at 2337.6 m (2315.0\r\nm TVD MSL), and the FWL was at 2372.1 m, (2349.5 m TVD MSL). Proven gross gas\r\ncolumn was 217 m (2120 -2337 m) and proven gross oil column was 34.5 m (2337 -\r\n2371.5 m). Reported oil shows began at 1910 m and ended at 2429 m. Evaluation\r\nof MDT data from well 36/7-1 showed the same pressure environment within the\r\noil zone of the Fensfjord Formation as in the wells 36/7-1 and 35/9-2. \u003c/p\u003e\r\n\r\n\u003cp\u003eA total of 280 m core was retrieved in\r\nnine cores from the interval 2124 m to 2429.5 m in the Sognefjord and Fensfjord\r\nFormations. MDT sampling was performed at 2443.5 m in the water zone.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 7\r\nMay 1996 as an oil and gas discovery.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eA successful production test was\r\nperformed in an approximately 12 m thick sandstone layer within the oil ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"765","properties":{"OBJECTID":765,"wlbNpdidWellbore":1801,"wlbName":"33/9-16","wlbHistory":"\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eExploration well 33/9-16 well is located\r\n1.8 km south of the recently drilled 33/9-15 well. It is located just north of\r\nStatfjord East and south of Statfjord North in the southern part of License PL\r\n172 updip from the 33/9-15 well and within the same seismically defined Intra\r\nDraupne deposits of Volgian age. The primary objective was to evaluate the\r\nhydrocarbon potential of the Late Jurassic (Volgian) Intra-Draupne Formation\r\nsandstone ("Munin sandstone unit") above the oil/water contact (2719\r\nm subsea), found in the 33/9-15 well. The secondary objective was to evaluate\r\nthe Middle Jurassic sands of the Brent Group.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 33/9-16 was spudded with the\r\nsemi-submersible installation "Ross Isle" on 28 November 1992 and\r\ndrilled to TD at 2870 m in the Middle Jurassic Ness Formation. The well was\r\ndrilled water based with sea water and hi-vis pills down to 407 m, sea water\r\nand PHB/PAC from 407 m to 1106 m, and with KCl/PHPA/PHB/PAC mud from 1106 m to\r\nTD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eIn the Upper Jurassic, the Intra Draupne\r\nFormation Sandstone was found as sandstones interbedded with thin siltstones. A\r\n4.3 m zone with oil shows was encountered in the uppermost part of this unit\r\nbased on shows while drilling and MWD. Three cores were cut in the Draupne\r\nFormation. Except for the top meter, the entire Intra Draupne sandstone unit\r\nwas cored. The top 4 m of the core consisted of a sandstone with good porosity\r\nand oil shows. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eIn the Middle Jurassic Brent Group, no\r\noil shows were observed in sandstones of the Tarbert and Ness Formations and as\r\na result no cores were cut. An RFT and an MDT sample were taken at 2685 and\r\n2684.5 m respectively and contained water and some gas but only t","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"766","properties":{"OBJECTID":766,"wlbNpdidWellbore":1808,"wlbName":"6305/12-1","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 6305/12-1 is located in the\r\nsouthwestern part of block 6305/12 in the Slørebotn Sub-basin, approximately 12\r\nkm west of the island of Vigra. The C-prospect is an easterly tilted fault\r\nblock bounded to the west by the Gossa High. The primary objective of the well\r\nwas to prove hydrocarbons in Early to Middle Jurassic sandstones. Late Triassic\r\nsandstones were secondary objectives. The well was designed to leave only\r\nnon-commercial resources up-dip with a total depth of 4300 m in rocks of\r\npresumed Late Triassic age. If the encountered stratigraphy below the base\r\nCretaceous was younger than expected, deeper drilling for stratigraphic\r\ninformation would be considered. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 6305/12-1 was spudded with\r\nthe semi-submersible installation Transocean 8 on 29 July 1991 and drilled to\r\nTD at 4302 m in Triassic Red Beds conglomerates. No significant problems were\r\nencountered during drilling, which was completed in 55 days compared to\r\nprognosed 81 days. The well was drilled with seawater and hi-vis pills down to\r\n721 m and with KCl/polymer mud from 721 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe Egga Informal Sand Unit was\r\nencountered at 1804 m. It contained ca 145 m net sand with 19.7% average\r\nporosity. Thinly developed sandstones were encountered from 3260 m in the Late\r\nCretaceous Lange Formation and down through to base Early Cretaceous at 3685 m.\r\nAt 3685 m there was a hiatus from Late Albian (Base Lange Formation) to\r\nBathonian, hence the Late Jurassic source rocks were not present in the well. The\r\nMiddle Jurassic unit exhibited interbedded thin sandstones, coals and\r\nclaystones. No shows were recorded while drilling the Egga sandstone, but\r\npost-well organic geochemical extraction proved a weak show at 1810 m. The logs\r\nshowed a water wet Egga reservoir. The Lange sandstones generally displayed\r\npoor direct and cut fluorescences while being drilled, and proved later to be\r\noil-bearing, though tight, in subsequent RFT runs. Moveable oil ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"767","properties":{"OBJECTID":767,"wlbNpdidWellbore":1810,"wlbName":"33/9-15","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThe 33/9-15 well is located on the\r\nnorthwestern flank of the Tampen Spur geological province, on the western\r\nmargin of the North Viking Graben. To the north of the well location lies the\r\nStatfjord Nord oil field with the main Statfjord oil field to the south and\r\nStatfjord Øst to the Southeast.\u00A0 Well 33/9-15 was drilled in the southern part\r\nof Licence PL172.\u00A0 The primary objective was to evaluate the hydrocarbon\r\npotential of a Late Jurassic Intra Draupne Sandstone unit, which was thought to\r\nbe similar to, or possibly associated with, the nearby Statfjord Nord field.\u00A0\r\nThe secondary objective was to evaluate Middle Jurassic sands of the Brent\r\nGroup.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well 33/9-15 was spudded with the\r\nsemi-submersible rig Sovereign Explorer on 23 April 1992 and drilled to TD at\r\n3007 m in the middle Jurassic Etive Formation. The well was drilled with\r\nseawater and hi-vis pills down to 416 m and with KCl / Polymer mud from 416 m\r\nto TD. Weak shows appeared on cores at the Mime Formation level. A thin oil\r\nzone was encountered at the top of the Munin sandstone unit of the Draupne\r\nFormation and two additional thin oil zones were seen further down in the Munin\r\nsandstone. No shows were seen in the Brent Group. Three RFT fluid samples were\r\ntaken in the Intra Draupne Formation Sandstone at 2743.5 m, 2783.2 m, and\r\n2829.8 m. They all contained water with trace of oil. The sample from 2829 m\r\ncontained sufficient oil for analysis, which gave an oil density of 0.859 g/cm3\r\n(33.1 API gravity). Eight cores were cut in the interval 2711 m to 2838 m, two\r\nin the Cromer Knoll Group, one from the base Mime Formation and into the upper\r\nDraupne Formation and the remaining five in the Draupne Formation.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 8\r\nJune 1992 as a dry hole with oil shows.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was performed\u003c/p\u003e\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"768","properties":{"OBJECTID":768,"wlbNpdidWellbore":1811,"wlbName":"30/9-13 S","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThe primary objective of the 30/9-13 S\r\nwell was to prove hydrocarbon potential in the Tarbert Formation in the G-East\r\nprospect, south west of the Oseberg Field. The well should define fluid\r\ncontacts in the prospect and test the sealing capacity of the eastern fault.\r\nThe location was chosen to drill through untruncated Tarbert Formation, and it\r\nshould leave a minimum of untested reserves up dip in order to establish the\r\nfluid contacts in the lower part of the Tarbert Formation.\u003c/p\u003e\r\n\r\n\u003cp\u003eAs secondary objectives the well should\r\ntest the resource potential within the Ness, Oseberg, Rannoch, Etive, Cook and\r\nStatfjord Formations. The well was planned deviated due to a very high\r\namplitude reflection, resulting in a shallow gas\u003c/p\u003e\r\n\r\n\u003cp\u003ewarning for a sand layer at 496 ± 10 m. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 30/9-13 S was spudded with\r\nthe semi-submersible installation Vildkat Explorer on 5 May 1991 and drilled to\r\na total depth of 4027 m in Early Jurassic Statfjord Formation sandstone. The\r\nwell was drilled with seawater and hi-vis pills down to 1030 m, with\r\nKCl/polymer mud from 1030 m to 3031 m, and with Thermadrill/KCl/polymer mud\r\nfrom 3031 m to TD. The well was drilled vertical to the 13 3/8" casing\r\nshoe and was kicked off from there using a steerable motor. A maximum\r\ninclination of 31 ° was obtained at 1434 m. At 1483 m the steerable system was\r\npulled and a drop assembly was run in hole to continue drilling. Intra Heather\r\nFormation Sandstone was encountered at 2959 m in the 12 l/4" hole before\r\nthe planned 9 5/8" casing point had been reached. The well was plugged\r\nback and casing was set above the hydrocarbon-bearing interval. On drilling out\r\nof the casing the well was sidetracked down to the top of the Heather Formation\r\nat 2963 m. The greater part of the Heather Formation proved to be sand with a\r\ntotal net gas column of 28.5 m. A total oil reservoir zone of 77 m with a 60 m\r\nnet pay zone was identified. A Free Oil Level","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"769","properties":{"OBJECTID":769,"wlbNpdidWellbore":1816,"wlbName":"30/10-6","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThe exploration well\r\n30/10-6 is situated in the central part of block 30/10, approximately 10km\r\nnorth of the Odin Field. The structure\r\nis part of the Jurassic fault block system forming at NE-SW trending complex from\r\nthe Frigg area to the Southeastern part of block 30/7. The objective of well 30/10-6 was to explore\r\nthe hydrocarbon potential of the Middle Jurassic Brent Group. Top Brent was\r\nprognosed at 5120 m.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well 30/10-6 was\r\nspudded 13 January 1992 by the semi submersible rig West Alpha and was completed the\r\n11 November 1992 at a TD of 5250 in the Middle Jurassic Ness Formation of the\r\nBrent Group. Due to too much inclination of the well, it had to be spudded\r\nthree times. The verticality was critical due to possible severe casing wear in\r\na deep well. After the third spud the drill string got stuck at 620 m in the\r\n26" section. Fishing was unsuccessful and as verticality was important the\r\nwell was respudded again. If plugging is not considered, the total duration of\r\nthe well was 206 days for the drilling part. This includes 22 days on the three\r\nfirst spuds and 184 days on the final well. Compared to the planned 114 days\r\n(114 = 125 -11 for P&A) this yields a total delay of 92 days. The well was\r\ndrilled with Bentonite mud down to 1420 m, with gypsum mud from 1420 m to 4368\r\nm, and with polymer mud from 4368 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eA seismic reflector\r\ndepth converted to 4850 m (+ /- 200m), was interpreted as a "Callovian\r\nUnconformity", possibly with sand stringers. This seismic reflector proved\r\nto be top Tarbert Formation at 4666 m. The Tarbert Formation could be divided\r\ninto two an Upper Sand (4666 m to 4815 m) and a Lower Sand (4884.5 m to 5207 m)\r\nseparated by a 70 m thick shale unit. The top part of the Upper Sand contained\r\ngas. It was not possible to establish a free water level or a gas/water\r\ncontact. The reservoir characteristics were poor and commercial production was\r\nnot found to be possibl","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"770","properties":{"OBJECTID":770,"wlbNpdidWellbore":1819,"wlbName":"34/7-18","wlbHistory":"\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 34/7-18 is located on the Vigdis\r\nField on Tampen Spur in the Northern North Sea. It was designed to drill and\r\ntest a Jurassic Prospect (Segment IV of the C Plus structure), between the\r\nSnorre and Tordis Fields. The well was drilled in a high position on a gently\r\ndipping structure where the top of the Brent Group is eroded. The primary\r\nobjective was to test the presence, reservoir quality and fluid contacts in the\r\nprospect. A secondary objective was to test the pressure regimes in the\r\nJurassic sequence, including possible depletion associated with pressure communication,\r\npreviously identified in the nearby Tordis Field. A boulder bed was expected at\r\n303 m, and shallow gas could occur at 394 m and 546 m.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 34/7-18 was spudded with the\r\nsemi-submersible installation West Alpha on 20 July 1991 and drilled to TD at\r\n2443 m in the Early Jurassic Drake Formation. Problems with retrieving core no\r\n2 led to 4 days lost while fishing. During plug and abandon the cut and pull\r\ntool twisted off and 9 x 8" DC and 7 x 5" HWDP was left on seabed.\r\nThree days were lost while clearing the seabed and cutting the casing and\r\nretrieving the well head, which was eventually retrieved using explosives.\r\nShallow gas was encountered in the pilot hole and a boulder bed was indicated\r\nfrom drilling parameters at 342 m. The well was drilled with spud mud down to\r\n1115 m, and with KCl mud from 1115 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eIn the Nordland and Hordaland Groups, the\r\nwell penetrated mainly claystones with relatively minor sandstone intervals. A\r\nPaleocene oil discovery was made, and two cores were cut in the Lista\r\nFormation, Rogaland Group. These were cut in the interval 1774 -1782 m, of\r\nwhich 6.3 m were recovered. RFT pressure measureme","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"771","properties":{"OBJECTID":771,"wlbNpdidWellbore":1822,"wlbName":"35/10-1","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well is located on the Marflo\r\nSpur, ca 15 km west of the Fram and Vega discoveries. The main objective was to\r\ntest the hydrocarbon potential of the Middle Jurassic Brent Group sandstones\r\nlocated in a rotated fault block. A secondary target was the Early Jurassic\r\nCook Formation. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 35/10-1 was spudded with the\r\nsemi-submersible installation Deepsea Bergen on 1 August 1991 and drilled to TD\r\nat 3986 m in the Early Jurassic Statfjord Formation. A 9 7/8" pilot hole\r\nwas drilled to 760 m where MWD indicated potential sand with shallow gas at 753\r\nm. Pilot hole was therefore plugged back to 740 m before opening up to 26"\r\nand running 20" casing. Electric logs did not confirm gas in the sand layer.\r\nThe 17 1/2" hole was drilled to 1895 m. The well started flowing (oil kick\r\nfrom 2 m thick Lista sand at 1892 m). The well was shut in and the drill pipe\r\nbecame stuck. The well was plugged back and sidetracked from kick-off point at\r\n735 m. At 3326 m in the 8 1/2" hole the well started flowing (salt water\r\nkick from the Brent Group). The hole was plugged back and 7" liner was run\r\nwith shoe at 3288 m. Further problems with lost circulation and gain caused by\r\ncoal beds occurred at 3986 m. The well was plugged back and abandoned at this\r\ndepth. Before logging, the well was plugged back to 3920 m; hence no electric\r\nlogs were run beyond 3860 m. The well was drilled with seawater/hi-vis pills\r\n/CMC EHV down to 736 m and with Gyp/PAC mud from 736 m to 1895 m. At this point\r\nan IMCOSPOT/PIPELAX pill was added to free the stuck pipe, without success.\r\nFrom sidetrack at 735 m the well was drilled to 3040 m using Gyp/PAC mud, and\r\nfrom 3040 m to TD the well was drilled with AncoTemp/bentonite/causticised\r\nlignite.\u003c/p\u003e\r\n\r\n\u003cp\u003eA 2 meter thick sand layer from 1891 m to\r\n1893 m in the Lista Formation, proved to be oil bearing (well kick, FMT sample\r\nat 1892 m). Both the Primary and secondary objectives proved to b","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"772","properties":{"OBJECTID":772,"wlbNpdidWellbore":1832,"wlbName":"31/5-4 AR","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 31/5-4 AR is a re-entry of the\r\nhorizontal side track well 31/5-4 A in the Troll West oil and gas province.\u003c/p\u003e\r\n\u003cp\u003e\u003cb\u003eOperationsand results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell bore 31/5-4 A was re-entered (31/5-4\r\nAR) with the semi-submersible installation Transocean 8 on 9 July 1991. The\r\nwell was suspended on 18 July 1991. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was performed\u003c/p\u003e\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"773","properties":{"OBJECTID":773,"wlbNpdidWellbore":1834,"wlbName":"2/5-9","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell \u003ca name=\"OLE_LINK2\"\u003e\u003c/a\u003e\u003ca\r\nname=\"OLE_LINK1\"\u003e2/5-9 \u003c/a\u003eis located in the vicinity of the 2/5-3 Sørøst Tor\r\nand the 2/5-4discoveries on the Steinbit Terrace in the southern North Sea. The\r\nmain objective was to test the hydrocarbon potential of the Late Jurassic sands\r\nin a rotated fault block, designated as the Magne structure. Secondary\r\nobjectives were to determine the reservoir quality of any sand prone intervals\r\npenetrated in the well, to determine the Jurassic stratigraphy in this easterly\r\npart of the Central Graben, and to establish seismic well ties into prospective\r\nacreage surrounding the Magne prospect.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 2/5-9 was spudded with the\r\nsemi-submersible installation West Vanguard on 10 September 1991 and drilled to\r\nTD at 5460 m (5443 m TVD) in the Late Jurassic Haugesund Formation. Pore\r\npressure reached a maximum estimated value of 15.9 ppg at TD. The well was kept\r\nvertical down to 4350 m, where angle started to build up to a maximum of 12.5\r\ndeg deviation at 4744 m. The deviation at TD was 10.4 deg. The well took 131\r\ndays to to complete, from spud to abandonment. A total of 36.8 days was\r\nunscheduled events, of which rig repair, malfunction of drilling equipment, and\r\nhole problems were the major contributors. Also an additional deepening from the\r\nauthorized TD at 5337 m to 5460 m in order to penetrate a reflector identified\r\nby wire line seismic logging (QSST checkshot) increased the pre-drill schedule.\r\nThe well was drilled with seawater and bentonite pills down to 960 m, with KCl\r\npolymer mud from 960 m to 2880 m, and with PHPA/KCl polymer mud from 2880 m to\r\nTD. No shallow gas zones were penetrated in the well.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe top Rogaland at 3126 m and top\r\nShetland Group at 3259 m came in 10 m and 17 m shallow to prognosis,\r\nrespectively. The top Early Cretaceous at","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"774","properties":{"OBJECTID":774,"wlbNpdidWellbore":1835,"wlbName":"15/12-8 A","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 15/12-8 was drilled ca 3.5\r\nkm east of the 15/12-4 well, which made the Varg oil discovery in Jurassic and\r\nTriassic sandstones. The main objective of the well was to test the potential\r\nfor hydrocarbons in sandstones of Oxfordian and Triassic age. Seismic anomalies\r\nat 437, 467, 479 and 803 m indicated possibility for shallow gas. Planned TD\r\nfor the well was 3260 m.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 15/12-8 was spudded with the\r\nsemi-submersible installation Deepsea Bergen on 5 June 1991 and drilled to TD at 3054 m in the Triassic Skagerrak Formation. No significant problems occurred\r\nduring operations. The well was drilled with seawater / hi-vis pills / CMC down\r\nto 615 m, with KCl/polymer mud from 615 m to 2855 m, and with Ancotemp/bentonite\r\nmud from 2855 m to TD. No shallow gas was encountered.\u003c/p\u003e\r\n\r\n\u003cp\u003eJurassic Vestland Group sandstone was\r\nencountered hydrocarbon-bearing at 2838 m. The hydrocarbon column extended 23 m\r\ninto Triassic sandstone of the Skagerrak Formation. The gas/water contact was\r\nestimated to 2877 m, confirmed by FMT pressure gradients and wire line logs. The\r\nwell was tested, and since no core was cut through the reservoir, the well was\r\nsidetracked at 2623 m with TD at 2940 m. The sidetrack was drilled with\r\nAncotemp/bentonite mud. Three conventional cores were cut in the interval 2841\r\n- 2902 m. The sidetrack was formally named 15/12-8 A.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe FMT tool was run in well 15/12-8 and\r\n15/12-8A. One segregated sample was taken at 2863 m in 15/12-8 (gas, condensate\r\nand mud filtrate) and another in the water zone at 2888 m in well 15/12-8 A (recovered\r\nmud only due to seal failure). \u003c/p\u003e\r\n\r\n\u003cp\u003eWell 15/12-8 was permanently abandoned on\r\n 14 July 1991 as a gas/condensate discovery. The 15/12-8 A sidetrack was\r\npermanently abandoned on 29 July as a gas/condensate appraisal well.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eOne DST test was performed in 15/12-8 in\r\nthe interval 2838 - 2869 m. The well produced gas-condensate with a de","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"775","properties":{"OBJECTID":775,"wlbNpdidWellbore":1836,"wlbName":"7128/6-1","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 7128/6-1 is located in the Finmark\r\nEast area on the Finmark Platform approximately 226 km east north east of\r\nHammerfest. The main objective of the well was to explore a bryozoan carbonate\r\nbioherm of the Røye Formation (Kungurian- Kazanian in age). Prognosed thickness\r\nof the carbonate was in excess of 180 m. The underlying Gzelian through\r\nArtinskian carbonate succession was seen as secondary objective. A third\r\nobjective was sandstones of the Billefjorden Group (Visean), but no closure had\r\nbeen mapped at this horizon in the prospect area. Shallow gas warning was given\r\nfor one interval at 369 m.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well is Type Well for the Tettegras,\r\nØrn, Isbjørn, and Røye Formations and Reference Well for the Soldogg and Falk\r\nFormations.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 7128/6-1 was spudded with\r\nthe semi-submersible installation Arcade Frontier on 11 August 1991 and drilled\r\nto TD at 2543 m in pre-Carboniferous Basement rocks. No shallow gas was\r\nencountered. No significant problems occurred during the drilling operation.\r\nThe well was drilled with seawater and hi-vis pills down to 833 m and with KCl\r\npolymer WBS/200 mud from 833 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eTop Røye Formation came in at 1623 m. The\r\nsecondary target, the Artinskian to Gzhelian limestone succession was\r\npenetrated from 1745.4 m to 2102 m. Basement was encountered at 2533.5 m.\r\nOverlying the basement is a thick sandstone\r\nsequence of Early Carboniferous age, the Soldogg Formation. Shows were recorded in limestone in the\r\ninterval from 1630 m down to 2076 and in a sandstone stringer at 2176. No shows in the Soldogg Formation.\r\nA total of 24 conventional cores were cut in the carbonate sequence yielding a\r\ntotal of 472.4 m core. A total of 139 sidewall cores were attempted and 137\r\nwere recovered. A total of 39 formation pressure tests were attempted and three\r\nfluid samples were collected. The fluid samples were all mud filtrate. Analysis\r\nindicated normal hydrostatic formation pressure. ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"776","properties":{"OBJECTID":776,"wlbNpdidWellbore":1838,"wlbName":"34/7-19","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 34/7-19 is an appraisal well on the\r\nVigdis Middle structure, south of the Snorre Field on Tampen Spur in the Northern North Sea. The well was drilled approximately 1.5 km north-west of well 34/7-16,\r\non a north-west dipping, rotated fault block. A wedge of partially eroded\r\nViking Group/Heather Formation was interpreted above the reservoir. The primary\r\nobjectives of the well were to prove the north-western extension of the 34/7-16\r\nreservoir into Segment M1 of the Vigdis Middle and establish an oil water\r\ncontact for the upper Brent Group. A secondary objective was to test the possible\r\nexistence of a Late Jurassic Draupne Formation shale wedge. The well was\r\ndesigned to be used in possible future field development. Shallow gas was expected\r\nat a depth of 445 m on the well location. This level represents a sand layer at\r\nTop Pliocene where gas had been observed in several previous wells in block\r\n34/7. Shallow gas could also be expected in thin sand layers, below seismic\r\nresolution down to Top Utsira Formation. A boulder bed could be expected\r\napproximately 60 m below sub seabed. Prognosed TD was estimated to 2803 m, and\r\nan OWC was assumed at 2418 m (2400 m MSL).\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 34/7-19 was spudded with the semi-submersible\r\ninstallation West Alpha on 24 September 1991 and drilled to TD at 2800 m in the\r\nEarly Jurassic Cook Formation. At core point, 2439 m the weather deteriorated.\r\nDue to extreme heave the top drive jumped out of hook. The drill pipe bent and\r\nthe top drive fell down on the drill floor. The shear ram was activated leaving\r\nthe drill string with core assembly in the hole. Fishing and WOW caused 4.5\r\ndays delay before coring could commence. The well was drilled with spud mud\r\ndown to 1166 m and with KCl mud from 1166 m to TD. Shallow gas was not\r\nencountered in this well, but a zone from 526 to 527.5 m was interpreted as\r\npotentially gas bearing. One boulder bed was encountered at 363 m.\u003c/p\u003e\r\n\r\n\u003cp\u003eDown to the Top Jurassi","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"777","properties":{"OBJECTID":777,"wlbNpdidWellbore":1839,"wlbName":"1/6-6","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 1/6-6 is located ca 2 km south of\r\nthe Albuskjell Field in the southern Norwegian North Sea. The principal\r\nobjective was to test the hydrocarbon potential of Middle and Late Jurassic\r\nsandstones on the southern flank of a faulted dip closure, partially underlying\r\nthe Albuskjell Chalk Field. It was proposed to drill to a total depth of 5355 m\r\nor 200 m below the interpreted Base Late Jurassic.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 1/6-6 was spudded with the\r\nsemi-submersible installation Dyvi Stena on 10 February 1992 and drilled to\r\nfinal TD at 5565 m (5562 m TVD), some 100 m into Triassic siltstone. The well\r\nachieved its objective, which entailed drilling 210 m deeper than plan, to a\r\nnew Norwegian depth record of 5565 m RKB. Maximum pore pressure in the well was\r\nestimated to have been 2.24 sg, higher than the worst-case scenario defined by\r\nthe well proposal. BHT was 190 deg C. Both pore pressure and BHT were the\r\nhighest yet encountered in Norway. The well was production tested under these stringent\r\nconditions. \u003c/p\u003e\r\n\r\n\u003cp\u003eIncluding additional time, the planned\r\nwork scope for the well was 179.5 days. It eventually took 395 days. Of these,\r\nonly 204.5 days (51.8%) was considered productive time. Five incidents\r\naccounted for 75% of lost time. These were: dropped 10-3/4" casing, failed\r\nwellhead, well control incident, failure of the HPC tieback packer and waiting\r\non weather. The problems involved two sidetracks. The dropped 10-3/4"\r\ncasing with TD at 4467 m led to the first sidetrack, which was made from kick-off\r\nat 2560 m. Then, after drilling to 3284 m and tripping out, a second sidetrack\r\nwas accidentally made from 2522 m.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was drilled with seawater and\r\nviscous sweeps to 1127 m and with gypsum / polymer mud from 1127 m to 4466 m in\r\nthe first hole. The first sidetrack was drilled with gypsum/polymer mud from\r\nkick-off to TD. The second and final sidetrack was drilled with VISPLEX for\r\nsidetracking, then with HF PLUS (glyc","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"778","properties":{"OBJECTID":778,"wlbNpdidWellbore":1840,"wlbName":"6507/2-2","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThe Dønna Terrace forms a large down\r\nfaulted block on the western margin of the Trøndelag Platform, situated between\r\nthe Nordland Ridge and the Vøring Basin. The structure to be tested by 6507/2-2\r\nis situated on the western edge of the Dønna Terrace. This structure was\r\nearlier tested by well 6507/2-1, which however left a considerable untested\r\ncolumn up-dip from the well position. The main target of the well was the\r\nJurassic reservoirs of Garn, Ile, and Tilje Formation. The secondary objectives\r\nwere to test the prospectivity of the Cretaceous sands in the Lysing and Lange\r\nFormations or at least to obtain stratigraphic information from these\r\nformations.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 6507/2-2 was spudded with\r\nthe semi-submersible installation Polar Pioneer on 21 October 1991 and drilled to TD at 3958 m in Early Jurassic sediments of the Åre Formation. The\r\nwell had 37% downtime due mainly to repeated occurrences of stuck drill pipe.\r\nDrilling went relatively smooth down to setting of the 9 5/8" casing shoe\r\nat 2760 m. After having cut two cores in the 8 1/2" section the well was\r\nshut in due to an influx at 3336 m. The well was killed with increased mud\r\nweight, but the pipe was found to be stuck. The pipe could not be freed and was\r\ncut at 3175 m. The well was then plugged back and sidetracked from 2989 m and\r\ndrilled to 3326 m with minor problems. A 7" liner was run and set with\r\nshoe at 3324 m and the 6" section was then drilled to 3737 where parts of\r\nthe bit sub was lost in the hole. This led to 20 days lost while attempting to\r\nrecover the fish and sidetrack past the fish. Eventually the fish was partly\r\nrecovered and drilling commenced to TD. The well was drilled with seawater and\r\nhi-vis pills down to 685 m and with a KCl/polymer mud from 685 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eOil shows were recorded on sandstone\r\nlaminae in the interval 2208 ? 2750 m in the Shetland Group. The Cretaceous\r\nLysing Formation was encountered at 2817.5 m","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"779","properties":{"OBJECTID":779,"wlbNpdidWellbore":1842,"wlbName":"34/8-6","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 34/8-6 was designed to drill North\r\nof the Visund Field on a northerly trending arm of the Tampen Spur. The main\r\nstructural feature in block 34/8, the A-structure, is a NNE-SSW oriented\r\nelongated rotated fault block with pre-Cretaceous strata dipping towards the\r\nWNW. The block contains the Visund field, and is divided into two compartments,\r\nthe A-south and the A-north, by a central fault. The well will test a\r\nstratigraphic trap on the northwest flank of the A-structure. From seismic\r\nanomalies possible shallow gas was expected at 510 m, 544 m, 556 m, and 877 m.\r\nLevels at 544 m, and 556 m are dipping sand layers, and could contain gas with\r\noverpressure. Scattered boulders could be expected between 424and 540 m. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe primary objective for well 34/8-6 was\r\nto test the presence of a hydrocarbon-bearing sand within the Upper Jurassic\r\nDraupne Formation, and was drilled close to the thickest portion of the\r\ninterpreted turbidite sand. Secondary objectives were to drill through the\r\nBrent Group to yield more information about development and thickness control\r\ndown dip of the structural crest, and to tag top of the Dunlin Group to permit\r\na good seismic tie-in, which can be carried up dip towards the Visund\r\nreservoir.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 34/8-6 was spudded with the\r\nsemi-submersible installation Transocean 8 on 21 September 1991 and at a depth\r\nof 3950 m in the Early Jurassic Drake Formation. The well was drilled with spud\r\nmud down to 1235 m and with KCl mud from 1235 m to TD. Drilling went on without\r\nany significant problems. Shallow gas indications were encountered during\r\ndrilling of the 8 1/2" pilot hole at 541 m and 550 m, but caused no\r\nproblems, and no gas was observed at the wellhead during drilling operations.\r\nThe gas indications did not correspond with any of the predicted sand layers. \u003c/p\u003e\r\n\r\n\u003cp\u003eThere was no sandstone developed at the\r\nprimary objective in the Draupne Formation. Crude oil appeared in the mu","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"780","properties":{"OBJECTID":780,"wlbNpdidWellbore":1846,"wlbName":"2/2-5","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThe main objective\r\nof the exploration well 2/2-5 was to test the hydrocarbon potential of the\r\nUpper Jurassic Ula Formation situated in the Epsilon structure. The structure\r\nis a salt induced anticline situated on a rotated, down thrown fault block in\r\nthe Ula-Gyda Fault zone.\u00A0The Oligocene\r\nVade Formation was the secondary target.\u00A0\r\nA seismic anomaly indicated a potential gas accumulation in this zone.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 2/2-5 was\r\nspudded by the semi submersible rig Treasure Saga on November 7 1991 and\r\ncompleted February 20 1992 in Permian Zechstein Group. The well was drilled with spud mud down to\r\n918 m, with KCl mud from 918 m to 3484 m, and with HITEMP Polymer mud from 3484\r\nm to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well penetrated\r\nmainly claystone with minor sandstone in Nordland, Hordaland, and Rogaland\r\nGroup.\u00A0The Vade Formation (within\r\nHordaland Group) proved to be water bearing.\u00A0\r\nAfter drilling throughout a typical sequence of the Shetland and Cromer\r\nKnoll groups, the top of the Tyne Group was encountered at 3418 m. The Ula Formation, which was reached at 3538\r\nm, consisted of an interbedded sequence of sandstone, siltstone, and shale.\u003c/p\u003e\r\n\r\n\u003cp\u003eA 5-meter thick oil\r\nbearing zone within the Ula Formation was encountered at 3671 m. An attempt made to obtain an oil sample\r\nusing RFT failed as the fluid chambers contained mud filtrate only. Geochemical\r\nanalyses of oil from the DST revealed an unusual chemical and isotopic\r\ncomposition unlike any oil in the area. Sediments interpreted to be Triassic\r\nage were penetrated at 3989 m and may represent either a fault gouge above salt\r\nor the up thrown fault block. The well was permanently abandoned as an oil\r\ndiscovery on 19 February 1992.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eOne DST test was\r\nperformed over the interval 3671.25 m to 3675.5 m. The well flowed oil at\r\nmaximum rate 600 Sm3 / day. The oil had a density of 0.86 g/cm3 and the GOR was\r\n44.\u003c/p\u003e\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"781","properties":{"OBJECTID":781,"wlbNpdidWellbore":1855,"wlbName":"30/6-24 S","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 30/6-24 S was drilled on the Delta\r\nStructure, some 5 km north of the main Oseberg Field area. The primary\r\nobjective was to test the hydrocarbon potential of the Statfjord Formation.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well was spudded with the\r\nsemi-submersible installation Vildkat Explorer on 13 October 1991 and drilled\r\nto TD at 3986 m (3742 m TVD). The well was offset from the target location and\r\ndeviated below 1035 m due to the proximity of a 30" gas pipeline above the\r\ntarget co-ordinates. An 8 1/2" pilot hole was drilled from 231 m to 422 m\r\nto check for shallow gas, but no shallow gas was found. The well was drilled\r\nwith spud mud down to 1017 m, with KCl mud from 1017 m to 3300 m, and with\r\nThermadril WBM mud from 3300 m to TD. When running the 9 5/8" casing it\r\nstuck at 3052 m. A spot of 25 m3 EZ spot/diesel was added to free the casing\r\nand this oil was in the mud down to 3974 m.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAn oil show was recorded on cuttings from\r\na limestone stringer at 2505 m. Top Jurassic, Dunlin Group came in at 3581 m.\r\nDunlin Group had sporadic weak shows on siltstone cuttings. Top of target\r\nreservoir Statfjord Group was encountered at 3683 m. It was water bearing with\r\noil shows on core no 1 in a 2-meter zone from 3686 m to 3688 m. Otherwise no\r\nhydrocarbon indications were recorded in the well.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eTwo cores were cut in the top of the\r\nStatfjord Group from 3682 m to 3712 m. No wire line fluid samples were taken.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was permanently abandoned on 6\r\nDecember 1991 as a dry well with shows.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eTesting\u003c/span\u003e\u003c/b\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo d","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"782","properties":{"OBJECTID":782,"wlbNpdidWellbore":1859,"wlbName":"6407/8-1","wlbHistory":"\r\n\r\n\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 6407/8-1 is located north of the\r\nNjord Field and east of the Draugen Field. The objective of the well was to\r\ntest an interpreted Late Jurassic submarine fan prospect within the Viking\r\nGroup. If successful, the well would prove a new play fairway on the Halten\r\nTerrace. No additional targets had been mapped at the well location.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 6407/8-1 was spudded with the\r\nsemi-submersible installation Ross Isle on 27 March 1992 and drilled to a total\r\ndepth of 4650 m in the Middle Jurassic Melke Formation. A 9 7/8" pilot hole\r\nwas drilled to 1100 m in the event of shallow gas. No gas was encountered. The\r\nwell was opened up and drilled with seawater and hi-vis pills down to 1106 m\r\nand with gyp/polymer mud from 1106 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eTop Viking Group was encountered at 4094\r\nm, 30m shallower than prognosis. No major sandstone was penetrated at prospect\r\nlevel or within the Viking Group.\u00A0 Minor sandstone and limestone horizons were\r\npenetrated within the Upper Cretaceous (Lange Formation,\r\nEarly Turonian). These horizons were hydrocarbon bearing, recorded on logs as\r\nwell as in the form of oil shows. Due to bad hole conditions no wire line logs\r\nwere run below 3491 m. MWD GR and resistivity logs were however run below this\r\ndepth. No cores were cut and no fluid samples were taken. The well was\r\npermanently abandoned on 7 June 1992 as a dry well with shows\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was performed\u003c/p\u003e\r\n\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"783","properties":{"OBJECTID":783,"wlbNpdidWellbore":1861,"wlbName":"2/7-21 SR","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 2/7-21 SR is a re-entry of well\r\n2/7-21 S, which tested oil and gas in undefined pre-Cretaceous rocks of the\r\nEmbla Field. The gas produced unexpectedly contained up to 40 ppm H2S in addition\r\nto ca 5% CO2. The purpose of the re-entry was further testing\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 2/7-21 SR was re-entered with the\r\nsemi-submersible installation West Delta on 13 September 1991.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe reservoir pressure and H2S content\r\nwas tested.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was completed on 14 October 1991\r\nand reclassified to development well 2/7-D-21.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was performed.\u003c/p\u003e\r\n\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"784","properties":{"OBJECTID":784,"wlbNpdidWellbore":1864,"wlbName":"6610/3-1","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 6610/3-1 is located ca 80 km\r\nsouthwest of the Røst Island in the Lofoten archipelago of Northern Norway. The\r\nmain objective was to test the hydrocarbon potential in the Early Jurassic\r\n(Tilje Formation) sandstones. A secondary objective was to test the possibility\r\nof development of sandy fans from Early Tertiary (Paleocene) to Early\r\nCretaceous.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 6610/3-1 was spudded with\r\nthe semi-submersible installation Deepsea Bergen on 29 October 1992 and drilled\r\nto TD at 3126 m in the Late Cretaceous, Lange Formation. Caving bridges caused\r\nwire line tools to hang-up and the severe weather conditions magnified the hole\r\nstability problems by the rig being disconnected several times. Due to long periods\r\nof wait on weather and upcoming drilling restrictions the decision was made to\r\ntemporarily plug and abandon. No logs exist from seabed to 402 m. The intervals\r\n402 m to 919 m and 2877.5 m to 3126 m were logged with MWD only. The well was\r\ndrilled with seawater and hi-vis pills down to 938 m and with gypsum/pac mud\r\nfrom 938 m to TD\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well encountered sandy fans of\r\nPaleocene and Late Cretaceous age. Shows were recorded in Intra Nise Sandstone\r\nat 2282 m to 2320 m, in Lysing sandstone from 2661 m to 2680 m, and in thin\r\nlimestone stringers in the Lange Formation at 3073 m and at 3167 m. FMT\r\npressure points gave water gradients in all reservoir sequences. Organic\r\ngeochemical analyses confirm good, scattered oil shows in Intra Nise sandstone\r\nfrom 2293.75 m to 2309.45 m. The shows were characterised as severely\r\nbiodegraded stains in an irregular pattern with no obvious relation to\r\nlithology. The other shows recorded while drilling were not confirmed by these\r\nanalyses, but they revealed an additional weak show on a sample from an intra\r\nTang Formation sandstone at 1675 m as well as a trace of oil in the FMT water\r\nsample from 1645 m. The thin claystones encountered in the Top Intra-Nise\r\nSandstone exhi","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"785","properties":{"OBJECTID":785,"wlbNpdidWellbore":1865,"wlbName":"2/1-10","wlbHistory":"\u003cb\u003e\r\nGeneral\r\n\u003c/b\u003e\r\n\u003cp\u003e\r\nThe well 2/1-10 was drilled on a prospect located within PL 164, 7.8km Northwest of Gyda Platform.\r\n The primary objective was to test the Upper Jurassic Ula Formation, if successfully,\r\nto prove a volume of oil that was commercial as a tie back development to the Gyda Platform.\r\n A secondary target was a younger Ula Formation interval.\r\n\u003c/p\u003e\r\n\u003cb\u003e\r\nOperations and results\r\n\u003c/b\u003e\r\n\u003cp\u003e\r\nThe wildcat well 2/1-10 was spudded on 9 November 1991 with the semi-submersible installation \"Ross Isle\",\r\nand was completed 14 January 1992 in the Triassic Skagerrak Formation. The well was drilled with sea water\r\nand hi-vis pills down to 1101 m and with KCl polymer mud from 1101 m to TD. The upper part of the Ula Formation was encountered at\r\n4189.5 m, 50 m deeper than originally predicted.  A 133 m thick Ula Formation was encountered instead of\r\n the most likely prognosed model of 15 to 30 m thick Ula formation (intra Farsund) sandstone, separated from underlying Ula\r\nSandstone by a 50 to 60 m thick Farsund mudstone.  The Ula Formation was cored from 4194 m to 4289.5 m.\r\n Fair quality shows was observed in uppermost 5 meter of sandstone only. 2/1-10 was plugged and abandoned as dry well.\r\n\u003c/p\u003e\r\n\u003cb\u003e\r\nTesting\r\n\u003c/b\u003e\r\n\u003cp\u003e \r\nNo drill stem test was performed\r\n\u003c/p\u003e\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"786","properties":{"OBJECTID":786,"wlbNpdidWellbore":1867,"wlbName":"2/1-9 A","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 2/1 ?9 A was drilled to appraise the\r\n2/1-9 discovery in the Late Jurassic "Gyda sandstone member" (Ula\r\nFormation), by side-tracking up-dip to the crest of the Gyda South structure. If\r\nsuccessful, the well could at a later stage be completed as a producer and tie\r\nback to Gyda platform. The structure is a fault/dip closure, which lies in the\r\nLate Jurassic fairway on the eastern flank of the Central Graben, 6 kilometres\r\nsouth of the Gyda field in the North Sea.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 2/1-9 was re-entered on 18 January 1992 by the semi submersible installation Ross Isle. The appraisal sidetrack\r\nwell 2/1-9 A was kicked off in the 8 1/2" hole from 3270 m in the Late\r\nCretaceous Tor Formation and drilled to TD 4379 m in the Late Jurassic Ula\r\nFormation. It took 25 1/2 days (18 1/2 days longer than planned) to drill to\r\ncoring point at 4140 m. This delay was mainly due to difficulties in\r\ncontrolling the directional tendencies of the BHA's, which required a number of\r\ncorrection runs. In addition, poor bit performance and harder than expected\r\nformations exacerbated the slow progress. Hole inclination was 52.8 degrees at\r\ncoring point. Problems were also experienced during TD logging with stuck\r\nlogging tools and stuck pipe whilst attempting to retrieve the tool. In\r\naddition a 9 bbl influx had to be circulated out during this time. The well was\r\ndrilled with Novamul ether-based mud from kick-off to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe target Ula Formation sandstone was encountered\r\nat 4099 m (3966 m TVD RKB). It was 120 m thick (TVD) and oil-bearing all\r\nthrough. The logs observed no OWC. \u003c/p\u003e\r\n\r\n\u003cp\u003eSix cores (178 m) were cut in the 8\r\n1/2" hole. All cores had 100% recovery with excellent shows being observed\r\nthroughout. Core 1 to 5 covered the sandstone of the Ula Formation while core 6\r\nentered into a mud stone member at the base. No H2S was observed whilst coring\r\n-despite having high level contingency due to H2S seen on well 2/1-9. The RFT\r\nwa","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"787","properties":{"OBJECTID":787,"wlbNpdidWellbore":1868,"wlbName":"7/7-2","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 7/7-2 is located ca 8 km east of the\r\n UK border on the Jæren High in the North Sea. It was the second commitment\r\nwell within the licence PL-148 and was designed to test the A-prospect,\r\ninterpreted as a Late Jurassic channel sandstone. Planned TD was in Permian\r\nsediments or 3500 m, whichever came first.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 7/7-2 was spudded with the\r\nsemi-submersible installation Deepsea Bergen on 20 January 1992 and drilled to\r\nTD at 3430 m in the Permian Zechstein Group. The well took 100 days to drill\r\nand test, 20 days more than planned. This was mainly due to a 25% higher pore\r\npressure than prognosed in the reservoir, resulting in a plug-back and 9\r\n5/8" casing above reservoir, and not at TD as programmed. Other\r\ncontributing factors were re-spud after lost stinger in 30" casing, two\r\noccasions of pulling BOP due to leakage and leak on swivel stem on top drive.\r\nThe DSTs experienced severe difficulties with leakage and operation of down\r\nhole valves resulting in two mis-runs with testing string and a shortened DST\r\nno. 2. The well was drilled with CMC EHV and seawater down to 904 m, with\r\nKCl/PHPA/PAC from 904 m to 2744 m, and with ANCOTEMP mud from 2744 m to TD. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe greater part of the prospect, the\r\nLate Jurassic Ula sandstone was encountered at 3327 m, and proved to be sandy.\r\nThe Jurassic reservoir lithology consisted primarily of fine, well-sorted\r\nsilica-cemented sandstone with poor visual porosity. Subsequent testing from\r\n3348 - 3350 m showed a very tight formation, however testing from 3333 - 3342 m\r\nyielded oil. No oil-water contact was encountered, but organic geochemical\r\nanalyses detected oil saturation in two intervals from the top of the\r\nreservoirs down to 3341, and from 3345 down to 3347 m. \u003c/p\u003e\r\n\r\n\u003cp\u003eFour and a half m of shaley core was\r\nrecovered in two cores from 3242 m to 3247 in the Mandal Formation. Good oil\r\nshows were observed in these cores. Organic geochemical analyses proved them","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"788","properties":{"OBJECTID":788,"wlbNpdidWellbore":1869,"wlbName":"7122/4-1","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 7122/4-1 was drilled in the\r\nNorthern part of the Hammerfest Basin. The objective of the well was to test\r\nthe Åsgard prospect, a large, tilted horst with Middle-Lower Jurassic\r\nsandstones of the Stø formation as the primary objective. The underlying\r\nNordmela and Tubåen formations were also considered to have potential for\r\nreservoired hydrocarbons. The trap was formed by a horst structure dipping\r\ntowards the North-Northwest. Well 7122/4-1 was the first well on this prospect.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 7122/4-1 was spudded with the semi\r\nsubmersible installation Sonate Arcade Frontier on 13 November 1991 and drilled\r\nto a total depth of 3015 m in the Triassic Snadd Formation. The well was\r\ndrilled with seawater and gel down to 815 m, with KCl/polymer from 815 m to\r\n2015 m, and with KCl/NaCl/Polymer from 2015 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eGood reservoir quality sandstones were\r\nencountered in the Stø and Nordmela Formations. Core analysis indicated\r\ngenerally good porosity and permeability. FMT's run in the Stø confirmed good\r\npermeability. However, analysis of the wire line logs indicated clearly that\r\nthe Stø and Nordmela sandstones are water wet. The Tubåen Formation consisted\r\nprimarily of sandstone, but was very thin in this well. Log analysis indicated\r\nthat these sandstones are also water wet. Thin, tight sandstones (interbedded\r\nwith claystone and siltstone) were present through much of the Triassic,\r\ngenerally decreasing in thickness with depth. From 2970 to 2990 m a Carnian\r\nsandstone was penetrated. The drill gas was higher through this zone than in\r\nany other sandstone in the well, averaging about 0.8 %. The cutting samples\r\nshowed the reservoir quality to be quite poor, with no visible porosity.\r\nNumerous unsuccessful attempts with the FMT tool to obtain a pressure\r\nmeasurement indicated that this zone has extremely low permeability. This was\r\nconfirmed by the log analysis. \u003c/p\u003e\r\n\r\n\u003cp\u003eHydrocarbon shows were first observed in\r\nthe Early Cret","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"789","properties":{"OBJECTID":789,"wlbNpdidWellbore":1872,"wlbName":"25/11-15","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 25/11-15 was drilled east of the\r\nBalder Field complex on the Utsira High in the North Sea.\u003c/span\u003e\u003cspan\r\nlang=EN-GB\u003e \u003c/span\u003e\u003cspan lang=EN-GB\u003eThe main objective was to test the\r\nhydrocarbon potential of the Paleocene Heimdal Sand in the Hermod prospect.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 25/11-15 was spudded with\r\nthe semi-submersible installation Transocean 8 on 10 November 1991 and drilled\r\nto TD at 2035 m in the Early Jurassic Statfjord Formation. Due to shallow gas\r\nwarning an 8 1/2" pilot was drilled from 239 to 390 m. No shallow gas was\r\nfound. The well was drilled with seawater and viscous bentonite sweeps down to\r\n1312 m and with KCl/PHPA/Polymer mud from 1312 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe Balder Formation was encountered at\r\n1660 m. It contained rare sandstone stringers close to the top and these had good\r\noil shows. This was the only oil show recorded outside of the Heimdal\r\nFormation. A 64 m thick Heimdal Formation Sandstone was penetrated from 1734 m\r\nto 1798 m. The sandstone was oil bearing down to a well-defined OWC at 1787 m.\r\nThe net pay thickness was 51.88 m with an average porosity of 34.5% and an\r\naverage Sw of 12.5%. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eSeven cores were cut from 1680 m to 1799\r\nm, starting 7 m below the top Sele Formation and ending 1 m below the base of\r\nthe Heimdal Formation. A total of 20 good RFT pressure points were recorded\r\ngiving a fluid density of 0.86 g/cc in the hydrocarbon bearing zone. Two fluid\r\nsamples were attempted, but were abandoned after problems with sand plugging.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was permanently abandoned on 25\r\nDecember 1991 as an oil Discovery.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eTesting\u003c/span\u003e\u003c/b\u003e\u003cspan lang=EN-GB\u003e","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"790","properties":{"OBJECTID":790,"wlbNpdidWellbore":1874,"wlbName":"34/10-35","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 34/10-35 was drilled on the Tjalve\r\nTerrace south-east of the Gullfaks South field in the Northern North Sea. The\r\nobjective was to test the hydrocarbon potential in the Brent Group between the Gullfaks\r\nSouth field and the 34/10-23 Valemon Discovery.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 34/10-23 was spudded with the\r\nsemi-submersible installation Ross Rig on 5 February 1992 and drilled to TD at 4310\r\nm in the Early Jurassic Statfjord Formation. No significant problems were\r\nencountered in the operations. The well was drilled water based with sea water\r\nand hi-vis pills down to 1083 m, gypsum/polymer mud from 1091 mud from 1091 m\r\nto 3783 m, and with Thermopol mud from 3783 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well penetrated Tertiary, Cretaceous\r\nand Jurassic rocks. The Middle Jurassic Brent Group was encountered at 3912.5\r\nm, unconformable below the Heather Formation. The Brent Group consisted of Ness\r\nFormation only. The underlying Dunlin Group came in with the Drake Formation at\r\n3941.5 m, and the Cook Formation at 3964.5 m. Gas and condensate was proven in\r\nthe Ness Formation and in the Cook formation down to top Burton Formation at\r\n4048 m. Pressure data clearly indicated no pressure communication between the\r\nNess and Cook Formation reservoirs. No gas-water contacts were established in\r\nthe well. Oil shows in traces of sandstones (direct and cut fluorescence) were\r\nrecorded over the interval 2030 m to 2100 m in the Lista and Våle formations\r\nand in the interval 2241 m to 2261 m in the Shetland Group. Cut fluorescence\r\nwas recorded also in shales from the Draupne and Heather formation.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eA total of 133.5 m core was cored in 13\r\ncores. Cores 1 to 11 were cut from 3939 m to 4078 m with variable recovery from\r\n33 to 100%.","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"791","properties":{"OBJECTID":791,"wlbNpdidWellbore":1875,"wlbName":"2/7-20 R","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 2/7-20 R is a re-entry of the Embla\r\ndiscovery well 2/7-20. The aim was plugging and re-use as producer well on the\r\nEmbla Field.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 2/7-20 was re-entered with the\r\nsemi-submersible installation West Delta on 14 October 1991. \u00A0\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was plugged on 1 November 1991\r\nand reclassified to development well 2/7-D-20.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eTesting\u003c/span\u003e\u003c/b\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo drill stem test was performed.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"792","properties":{"OBJECTID":792,"wlbNpdidWellbore":1878,"wlbName":"2/7-27 S","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 2/7-27 S was drilled on the Embla\r\nstructure in the southern North Sea. The objective was to drill to replace the\r\nabandoned 2/7-23 S well as a production well in the Embla reservoir. Well\r\n2/7-27 S would thus be drilled as close as possible to the 2/7-23 S well path\r\nand to the same bottom hole location. By this it was anticipated that the\r\nextensive core data recovered in the 2/7-23 S would be applicable to the\r\nproduction data to be gained from the 2/7-27 S. The 2/7-23 S had earlier\r\nconfirmed the presence of hydrocarbon bearing sandstones originally discovered\r\nin the 2/7-9 (1974), and later tested in the 2/7-20 (1988) and 2/7-21 S (1989)\r\nwells, but was abandoned before well testing could be performed.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 2/7-27 S was spudded with\r\nthe semi-submersible installation West Delta on 9 November 1991 and drilled to\r\nTD at 4801 m (4452 m TVD) in pre-Jurassic rocks. It was drilled deviated from a\r\nfifteen slot production template located at the site of the planned Embla\r\nproduction facilities. Drilling problems with stuck pipe were encountered in\r\nthe 12 1/4" hole section at 3470 m, forcing a technical sidetrack from\r\n2972.7 m. Unlike previous Embla wells, the 2/7-27S was drilled using water\r\nbased mud throughout. It was drilled with seawater and hi-vis pills down to 573\r\nm, with KCl/polymer mud from 573 m to 3791 m, with Baranex-Thermathin mud from 3791\r\nm to 4500 m, and with a Thermadrill/Baranex high temperature mud system from\r\n4500 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe 2/7-27 S well encountered top Mandal\r\nFormation at 4476 m and top pre-Jurassic reservoir at 4483.3 m (4177.6 m TVD)\r\nwith the same reservoir stratigraphy as the 2/7-23S. However, although the\r\nwells are only 46.5 m apart at the Base Cretaceous Unconformity, th","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"793","properties":{"OBJECTID":793,"wlbNpdidWellbore":1879,"wlbName":"35/11-6","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eBlock 35/11 is located on the\r\nnorthwestern edge of the Horda Platform, on the Lomre and Uer Terrace. The\r\nNorthern part of the Viking Graben is immediately to the Northwest. The block\r\nlies due north of the Troll Field. The well was drilled to appraise the 35/11-2\r\nDiscovery, which proved oil and gas in the Middle Jurassic and had shows in\r\nLate Jurassic Intra Heather Sandstones. The primary objective was to evaluate\r\nthe Middle Jurassic sandstones of the Brent Group, and the location was chosen\r\nsuch that the OWC of the Tarbert Formation could be identified. The secondary\r\nobjective was the Late Jurassic Intra Heather Sandstones, which were thought to\r\nbe much thicker than in the 35/11-2 location. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 35/11-6 was spudded with the\r\nsemi-submersible installation Sovereign Explorer on 30 January 1992 and drilled\r\nto TD at 3990 m in the Early Jurassic Statfjord Formation. The well was drilled\r\nwith seawater and viscous pills to 985 m and with KCl/polymer mud from 985 m to\r\nTD. In the Late Jurassic, sandstones were found in the Upper Heather and\r\nSognefjord Formations. In the Upper Heather Formation a very porous and\r\npermeable sandstone contained 1.2 m of oil. A core was taken at the base of\r\nthis interval and an RFT sample at 3072.7 m recovered gas and heavy oil. RFT\r\npressure and sampling data indicated that the zone had excellent permeability\r\nin places. The pressure data did not support communication with 35/11-2, and a\r\nlarge sampling pressure draw down indicated a limited accumulation. The\r\nsandstone in the Sognefjord Formation, although thicker, was much less porous\r\nand contained only traces of residual oil. Two cores were taken in this\r\nFormation and an RFT at 3174.5 m recovered only traces of hydrocarbons. In the\r\nMiddle Jurassic Brent Group, shows were observed in cores but these were\r\nprobably residual as petrophysical results showed only low oil saturations. The\r\nreservoir quality of the sandstones was generally p","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"794","properties":{"OBJECTID":794,"wlbNpdidWellbore":1881,"wlbName":"35/12-1","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well 35/12-1 was drilled on the\r\neastern border of the block 35/12 against a north-south oriented main fault,\r\nwhich is the eastern limit of the Uer Terrace. The primary purpose of the well\r\nwas to test the hydrocarbon potential in sandstones of the Late Jurassic\r\nSognefjord Formation. A secondary objective was to test the reservoirs of the\r\nBrent and Dunlin Groups.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 35/12-1 was spudded with the semi\r\nsubmersible rig Treasure saga on the 27 February 1992 and was drilled to TD at\r\n3020 m in Early Jurassic (Early Pliensbachian - ?Sinemurian) rocks. The well\r\nwas drilled with spud mud down to486m,with gel mud from 486 m to 1020 m,and with KCL mud from 1020 m to\r\nTD.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well penetrated mainly claystones\r\nwith minor sandstone intervals in the Nordland and Rogaland Groups. Shetland\r\nand Cromer Knoll Groups consisted mainly of claystones with limestones and\r\nmarls. The well encountered 37 m of Draupne. Top Heather Formation was\r\npenetrated at 2398 m. The reservoir quality in the Heather Formation was poor.\r\n The formation consists of siltstone and some thin beds of fine sandstones with\r\nlow porosity.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe sandstones in the Sognefjord\r\nFormation and the Fensfjord Formation sandstone had better reservoir quality\r\nwith porosities around 20% in the Fensfjord Formation. Sandstones were also\r\npresent in the Brent and Dunlin Groups. Some weak traces of hydrocarbons were\r\nobserved in sandstone lamina on cores from the Upper parts of the Heather\r\nFormation. Weak traces of shows were recorded also in the Fensfjord Formation\r\nand into the Brent Group. Petrophysical evaluation showed that the sandstones\r\nof Jurassic age were water filled. The well was terminated 17 m into what was\r\ninitially believed to be basement rocks, but which was shown by post-well\r\nanalyses to be undifferentiated Early Jurassic sediments about 120 meters\r\nshallower than prognosis. Three cores were cut in the Heather Formation from\r\n2415 m to 2458.5 m. ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"795","properties":{"OBJECTID":795,"wlbNpdidWellbore":1883,"wlbName":"35/11-4 R","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 35/11-4 discovered oil and gas in\r\nthe Sognefjord and Fensfjord Formations and the Brent Group. The discovery was\r\nmade by shows, logs, FMT pressure gradients and sampling using the dynamically\r\npositioned installation Yatzy. This re-entry, 35/11-4R, was made to appraise\r\nthe 35/11-4 discovery by Drill Stem Testing. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 35/11-4R was entered with the\r\nsemi-submersible installation Sovereign Explorer on 16 November 1991. This rig\r\nhas an RKB of 27 m compared to 17 m for the rig Yatzy. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 27\r\nJanuary 1992 as an oil and gas discovery.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eFour drill stem tests were carried out,\r\none in the oil zone of each of the Brent Group, Fensfjord, lower Sognefjord and\r\nupper Sognefjord reservoirs. DST's 1 (2686.7 - 2694.2 m), 2B (2296.1 - 2303.1\r\nm) and 3 (2044.0 - 2056.0 m) flowed oil from the Brent, Fensfjord and lower\r\nSognefjord reservoirs respectively. DST 4B (2010.0 - 2013.0 m) flowed oil and\r\nfree gas from the upper Sognefjord Formation. Note that the test intervals here are referenced to the Sovereign Explorer RKB. Subtract ten meters to obtain the test intervals used in many of the 34/11-4R well reports, where the Yatzy RKB is used as datum.\u003c/p\u003e\r\n\r\n\u003cp\u003eBottom-hole sampling was carried out in\r\nDST 1, sampling oil from the Brent Group to obtain samples for direct PVT\r\nanalysis. Surface oil and gas sampling was carried out in all four DST's to\r\nobtain samples for recombination and PVT analysis.\u003c/p\u003e\r\n\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"796","properties":{"OBJECTID":796,"wlbNpdidWellbore":1885,"wlbName":"31/2-17 S","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell bores 31/2-17 S, -A, and -B were\r\ndrilled on the north-western periphery of the Troll West gas and oil discovery.\r\nThe objective was to obtain the thickness of the oil zone and reservoir\r\nproperties in the "Intermediate Area". Well bores 31/2-17 S and\r\n31/2-17 A are located on each side of a fault subdividing the Intermediate Area\r\ninto two main compartments. Well 31/2-17 S is located on the eastern side of\r\nthe fault. The side track 31/2-17 A was turned 180 degrees and landed on the\r\nwestern side of the fault. Well 31/2-17 B was side-tracked from well 31/2-17 A\r\nand drilled horizontally to a position about 5 m above the oil water contact.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eAll three well bores were drilled with\r\nthe semi-submersible installation Transocean 8 from the same wellhead location.\r\nOperations commenced with spud of 31/2-17 S on 28 December 1991 and ended with\r\ntemporary abandonment of 31/2-17 B on 14 February 1992. \u003c/p\u003e\r\n\r\n\u003cp\u003eWell 31/2-17 S was drilled to TD at 2220\r\nm in the Middle Jurassic Fensfjord Formation. No significant technical problem\r\noccurred in the well bore. The well bore was drilled with sea water and hi-vis\r\npills down to 921 m and with KCl/brine/PHPA mud from 921 m to TD. One and a\r\nhalf m of Draupne Formation was penetrated at 1870 m. The Sognefjord Formation\r\nreservoir was encountered with gas at 1871.5 m. The Gas-Oil-Contact was\r\npenetrated at 1972 m (1544.2 m TVD MSL) and the Oil-Water-Contact was\r\npenetrated at 2011 m (1565.8 m TVD MSL), both contacts in the Heather\r\nFormation. Six cores were taken. Core one and two and the upper part of core\r\nthree were cut in the Sognefjord Formation. The rest of the cores were cut in\r\nthe Heather B Formation. No fluid sample was taken.\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 31/2-17 A was kicked of from 31/2-17\r\nS at 909 m and drilled to TD at 1924 m in the Middle Jurassic Fensfjord\r\nFormation. No significant technical problem occurred. The well bore was drilled\r\nwith KCl/brine/PHPA mud from kick-off to 1012 m","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"797","properties":{"OBJECTID":797,"wlbNpdidWellbore":1898,"wlbName":"31/2-17 A","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell bores 31/2-17 S, -A, and -B were\r\ndrilled on the north-western periphery of the Troll West gas and oil discovery.\r\nThe objective was to obtain the thickness of the oil zone and reservoir\r\nproperties in the "Intermediate Area". Well bores 31/2-17 S and\r\n31/2-17 A are located on each side of a fault subdividing the Intermediate Area\r\ninto two main compartments. Well 31/2-17 S is located on the eastern side of\r\nthe fault. The side track 31/2-17 A was turned 180 degrees and landed on the\r\nwestern side of the fault. Well 31/2-17 B was side-tracked from well 31/2-17 A\r\nand drilled horizontally to a position about 5 m above the oil water contact.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eAll three well bores were drilled with\r\nthe semi-submersible installation Transocean 8 from the same wellhead location.\r\nOperations commenced with spud of 31/2-17 S on 28 December 1991 and ended with\r\ntemporary abandonment of 31/2-17 B on 14 February 1992. \u003c/p\u003e\r\n\r\n\u003cp\u003eWell 31/2-17 S was drilled to TD at 2220\r\nm in the Middle Jurassic Fensfjord Formation. No significant technical problem\r\noccurred in the well bore. The well bore was drilled with sea water and hi-vis\r\npills down to 921 m and with KCl/brine/PHPA mud from 921 m to TD. One and a\r\nhalf m of Draupne Formation was penetrated at 1870 m. The Sognefjord Formation\r\nreservoir was encountered with gas at 1871.5 m. The Gas-Oil-Contact was\r\npenetrated at 1972 m (1544.2 m TVD MSL) and the Oil-Water-Contact was\r\npenetrated at 2011 m (1565.8 m TVD MSL), both contacts in the Heather\r\nFormation. Six cores were taken. Core one and two and the upper part of core\r\nthree were cut in the Sognefjord Formation. The rest of the cores were cut in\r\nthe Heather B Formation. No fluid sample was taken.\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 31/2-17 A was kicked of from 31/2-17\r\nS at 909 m and drilled to TD at 1924 m in the Middle Jurassic Fensfjord\r\nFormation. No significant technical problem occurred. The well bore was drilled\r\nwith KCl/brine/PHPA mud from kick-off to 1012","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"798","properties":{"OBJECTID":798,"wlbNpdidWellbore":1899,"wlbName":"31/2-17 B","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell bores 31/2-17 S, -A, and -B were\r\ndrilled on the north-western periphery of the Troll West gas and oil discovery.\r\nThe objective was to obtain the thickness of the oil zone and reservoir\r\nproperties in the "Intermediate Area". Well bores 31/2-17 S and\r\n31/2-17 A are located on each side of a fault subdividing the Intermediate Area\r\ninto two main compartments. Well 31/2-17 S is located on the eastern side of\r\nthe fault. The side track 31/2-17 A was turned 180 degrees and landed on the\r\nwestern side of the fault. Well 31/2-17 B was side-tracked from well 31/2-17 A\r\nand drilled horizontally to a position about 5 m above the oil water contact.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eAll three well bores were drilled with\r\nthe semi-submersible installation Transocean 8 from the same wellhead location.\r\nOperations commenced with spud of 31/2-17 S on 28 December 1991 and ended with\r\ntemporary abandonment of 31/2-17 B on 14 February 1992. \u003c/p\u003e\r\n\r\n\u003cp\u003eWell 31/2-17 S was drilled to TD at 2220\r\nm in the Middle Jurassic Fensfjord Formation. No significant technical problem\r\noccurred in the well bore. The well bore was drilled with sea water and hi-vis\r\npills down to 921 m and with KCl/brine/PHPA mud from 921 m to TD. One and a\r\nhalf m of Draupne Formation was penetrated at 1870 m. The Sognefjord Formation\r\nreservoir was encountered with gas at 1871.5 m. The Gas-Oil-Contact was\r\npenetrated at 1972 m (1544.2 m TVD MSL) and the Oil-Water-Contact was\r\npenetrated at 2011 m (1565.8 m TVD MSL), both contacts in the Heather\r\nFormation. Six cores were taken. Core one and two and the upper part of core\r\nthree were cut in the Sognefjord Formation. The rest of the cores were cut in\r\nthe Heather B Formation. No fluid sample was taken.\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 31/2-17 A was kicked of from 31/2-17\r\nS at 909 m and drilled to TD at 1924 m in the Middle Jurassic Fensfjord\r\nFormation. No significant technical problem occurred. The well bore was drilled\r\nwith KCl/brine/PHPA mud from kick-off to 1012 m","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"799","properties":{"OBJECTID":799,"wlbNpdidWellbore":1906,"wlbName":"2/7-28","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eExploration well 2/7-28 was drilled on\r\nthe Eldfisk Jurassic Prospect, on the flank of the Eldfisk Field on the western\r\nside of the Feda Graben in the North Sea. The well was positioned 1.8\r\nkilometres west of the Eldfisk Alpha Platform. The primary objective was to\r\nprove hydrocarbons in sandstones in the Late Jurassic Eldfisk Formation. The\r\nEldfisk Formation is interpreted as high density turbidite/debris flow deposits\r\nlocated on the eastern side of the major northwest-southeast trending Skrubbe\r\nFault. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 2/7-28 was spudded with the jack-up\r\ninstallation Mærsk Guardian on March 8, 1992 and drilled to TD at 3893 m, 54 m\r\ninto the Late Permian Zechstein Group. Drilling to the Upper Palaeocene Section\r\nproceeded without major difficulty, but the 11 3/4" liner was set higher\r\nthan prognosed because of a combination of lost circulation in the Lower\r\nPalaeocene Våle Formation and instability in the Tertiary section above. A\r\nprognosed depleted chalk reservoir horizon, the flank of the Eldfisk Field, necessitated\r\nsetting 9 7/8" casing at top of the Ekofisk Formation. Drilling proceeded\r\nto 3050.4 m in the Lower part of the Hod Formation, the proposed setting for\r\nthe 8 3/4" casing. While under-reaming before running the linear, an\r\nunder-reamer arm was lost in the hole. A successfully sidetrack hole was made\r\nbelow the liner. Drilling continued to 3061.1 m where the bottom hole assembly\r\ntwisted off. The hole was sidetracked again and drilling continued to base of\r\nthe Early Cretaceous where 7" liner was set. Further drilling to final TD\r\nwent without significant difficulties. The well was drilled water based with spud\r\nmud down to 745 m, polymer mud from 745 m to 8313 m, sea water/Drispac/Soltex\r\nmud from 8313 m to 9304 m, polymer mud from 9304 m to 1","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"800","properties":{"OBJECTID":800,"wlbNpdidWellbore":1907,"wlbName":"25/11-14 SR","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 25/11-14 SR re-entry was drilled\r\ncentrally on the Balder Field on the Utsira High in the North Sea. This field\r\nwas discovered in 1967 by the 25/11-1 well, and was the first well on the\r\nNorwegian shelf that proved oil. Primary well 25/11-14 S was planned to be\r\ncompleted for a long term test by the FPV Petrojarl 1. The well was planned\r\ndeviated with kick-off at 1060 m in order to avoid possible shallow gas at 235\r\nm, 254 m, and 515 m. The main objective of this well was to test two Paleocene Heimdal\r\nFormation sands; the IB4 sand at 1863 m and the IB3 sand at 1897 m. The Heimdal\r\nFormation had previously proved oil-bearing in the three neighbouring wells\r\n25/11-6, -7, and -8. Eocene sands constituted a secondary objective for testing.\r\nBased on data from surrounding wells, no abnormal pressure was expected. The\r\nsurface location and well trajectory for this well, was designed so that a\r\nlater plug-back and sidetrack to a horizontal completion could be accomplished.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe 25/11-14 SR re-entry was made to\r\nfulfil the primary objective of well 25/11-14 S, which was terminated too\r\nshallow and without logging and testing due to stuck pipe.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 25/11-14 SR kicked off at 1571\r\nm in 25/11-14 S on 19 October 1990. It was drilled with the semi-submersible\r\ninstallation Byford Dolphin to final TD at 2081 m in sands of the Paleocene\r\nHeimdal Formation IB3 sand. After coring the IB3 sand the well was drilled a\r\nfurther 11 m but was TD'ed early as it encountered lost circulation problems\r\nbetween 2077 and 2081 m. It was decided at this point to run casing as quickly\r\nas possible to avoid further formation damage prior to the well's main\r\nobjective of the extended production test. The well was drilled with seawater\r\ndown","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"801","properties":{"OBJECTID":801,"wlbNpdidWellbore":1908,"wlbName":"34/4-8","wlbHistory":"\u003cb\u003e\r\nGeneral\r\n\u003c/b\u003e\r\n\u003cp\u003e\r\nWell 34/4-8 is located on the \"Beta Terrace\", a down faulted terrace northwest of the Snorre Block in the central part of the block. The main objective of well 34/4-8 was to test the presence of hydrocarbons and the reservoir quality of the Statfjord Formation on the Beta Terrace. The well should also test the presence of hydrocarbons in the Lunde Formation, improve depth conversion and seismic tie for the pre-Cretaceous levels in this previously undrilled structural element, and give indications on further prospectivity north-westwards in block 34/4. \r\n\u003c/p\u003e\r\n\u003cb\u003e\r\nOperations and results\r\n\u003c/b\u003e\r\n\u003cp\u003e\r\nWildcat well 34/4-8 was spudded with the semi-submersible installation \"Vildkat Explorer\" on 22 May 1994 and drilled to TD at 3110 m in the Triassic Lunde Formation. Since possible shallow gas levels had been predicted, a 9 7/8\" pilot hole was first drilled. No shallow gas was found. The well was drilled with spud mud and gel down to 1460 me and with KCl mud with a glycol additive from 1460 m to TD. \r\n\u003c/p\u003e\r\n\u003cp\u003e\r\nThe Nordland and Hordaland Groups were mainly silty claystones except for the sandy Utsira Formation, which came in at 1123 m. The Nordland and Hordaland Groups had a very high content of drilling gas (average 2-3%), but no signs of gas were seen on the logs. The Rogaland Group was penetrated at 1690 m, and consists of the Balder and Sele Formations. The Balder Formation was dominated by tuff interbedded with claystone. The Sele Formation consisted of silty claystones with traces of limestones. At 1838 m the Shetland Group was penetrated. The Shetland Group consisted predominantly of silty clay stone with some limestones and thin sandstone beds. The Cromer Knoll Group had marl as the main lithology. The marl was interbedded with silty claystones and sandstones. The Dunlin Group consisted of claystone interbedded with marl and minor sandstone beds. The Statfjord Formation was penetrated at 2799 m and consisted of sandstones alternating with shale/claystones.\r\nThe Hegre Group proved to be","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"802","properties":{"OBJECTID":802,"wlbNpdidWellbore":1909,"wlbName":"34/8-4 A","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 34/8-4 A on the Visund Field was\r\ninitiated as a sidetrack to well 34/8-4 S, which had been temporarily plugged\r\nand abandoned. The original well had missed the planned Statfjord Formation\r\ntarget due to structural complexities of the area. The sidetrack should reach\r\nthe target location, Statfjord Formation, approximately 420 m north-northwest\r\nof the surface location in an area of good seismic control. The main objective\r\nwas to test Statfjord Formation hydrocarbon potential, fluid composition and\r\naquifer characteristics. Secondary objectives were to evaluate the Lunde\r\nFormation B/C aquifer characteristics, to establish stratigraphic control of\r\nthe Base Cretaceous - top Statfjord interval, and to determine the mechanism\r\nfor hydraulic communication with the Brent reservoir in well 34/8-4S through\r\ngravity slide Brent segment and/or through Dunlin Group reservoir.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 34/8-4 S was re-entered with the\r\nsemi submersible installation Transocean 8 on 18 February 1992. The sidetrack\r\n34/8-4 A was kicked off from below the 13 3/8" shoe at 2187 m in the\r\nprimary well bore and drilled to TD at 3567 m in the late Triassic Lunde\r\nFormation. No significant problems were encountered during drilling. The well\r\nwas drilled with a KCl / polymer mud from kick-off to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eA major unconformity was found between\r\nthe top of the Early Jurassic (Pliensbachian) at 2902.5 m and the overlying\r\nEarly Cretaceous (Hauterivian). A sandstone member of the Amundsen Formation\r\nwas encountered from 2942 m to 2989.5 m. One core was taken in this unit and\r\nrecorded good hydrocarbon shows. Subsequent wire line logs and DST results\r\nconfirmed that the interval is oil bearing. A gross reservoir thickness of 31.0\r\nm was defined, giving a net pay thickness of 22.38 m. The Statfjord Formation\r\noccurred between 3057 m and 3143 m. A total of 7 cores were cut through this\r\ninterval. Good oil shows were observed throughout.The Lunde Formation was prese","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"803","properties":{"OBJECTID":803,"wlbNpdidWellbore":1920,"wlbName":"25/11-16","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 25/11-16 was drilled south of the\r\nBalder Field complex on the Utsira High in the North Sea. The main objective was\r\nto test the hydrocarbon potential of the Heimdal Formation within the\r\n"Hanna" mound. Possible younger sand developments in the Lista and\r\nSele Formations were secondary targets.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 25/11-16 was spudded with\r\nthe semi-submersible installation Vildcat Explorer on 29 June 1992 and drilled\r\nto TD at 1945 m in the Late Cretaceous Hod Formation. The well was drilled with\r\nspud mud down to 1339 m and with CaCO3/Nacl mud from 1339 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe primary target Heimdal Formation was\r\nencountered from 1767 m to 1872 m. Gross thickness is 105.75 m with 83.9 m net\r\nsand. The formation was oil bearing with 18.87 m net pay of heavy oil (0.85\r\ng/cc at reservoir conditions) down to a series of claystone beds at 1786 m. The\r\naverage porosity in the oil zone was 37.5% and the average Sw was 12.8%. The\r\nreservoir sand is very poorly consolidated, homogenous and has a net to gross\r\nratio in the oil zone of 0.96. The average range of both horizontal and\r\nvertical permeabilities is 10 to 14 Darcies. A free water contact was\r\nestablished at 1793 m from MDT data. The oil/water contact appears to occur at\r\nthe base of the sand unit at ca 1790 m (1765 m TVD MSL). In addition to oil\r\nshows in the Heimdal Formation oil zone oil two isolated shows were recorded in\r\nthin sand stringers at 1713 m in the Balder Formation and at 1735 m in the Sele\r\nFormation.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eA total of 200 m core was recovered from\r\n14 cores taken in the interval 1699 m to 1914 m (93% recovery), starting 1 m\r\nbelow the top of the Balder Formation and ending 17 m into the Tor Formation. A\r\ntotal of 2","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"804","properties":{"OBJECTID":804,"wlbNpdidWellbore":1921,"wlbName":"25/11-17","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 25/11-17 is\r\nlocated south of the Balder / Grane area. The objective of the well was to test\r\nthe hydrocarbon potential of sands of both Jurassic and Paleocene age. The\r\nlocation was chosen such that it left minimum reserves up dip in the Jurassic\r\nprospect while simultaneously penetrating the Paleocene prospect above the\r\nexpected regional oil water contact. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eExploration well 25/11-17 was\r\nspudded with the semi-submersible installation "West Delta" on 1\r\nMarch 1993 drilled to a total depth of 2256 m, 13 m into metamorphic basement.\r\nThe well was drilled water based with spud mud down to 1413 m and with KCl /\r\nPolymer from 1413 m to TD. \u003c/p\u003e\r\n\r\n\u003cp\u003eReservoir sands were\r\nencountered in the Balder Formation from 1590 m to 1646 m but no shows were seen\r\nand the reservoir proved to be water bearing. Reservoir sands were also\r\nencountered in the Statfjord Formation from 1998 m to 2038 m but again no shows\r\nwere seen and the reservoir proved to be water bearing. Overlaying the basement\r\nthe well penetrated a 10 m thick layer of regolith (weathered rock). Seven\r\nconventional cores were cut from 1625.5 m to 1759.6 m, starting in the middle\r\nof the Balder Formation, continuing through the Sele, Lista and Våle Formations\r\nand ending in the Tor Formation. An eighth core was cut from 2018 m to 2037 m\r\nin the lower part of the Statfjord Formation and into the regolith layer, and a\r\nfinal ninth core was cut at TD in the metamorphic basement from 2248 m to 2256\r\nm. No fluid samples were taken. The well was permanently abandoned as a dry\r\nwell on 22 March 1993.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test\r\nwas performed.\u003c/p\u003e\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"805","properties":{"OBJECTID":805,"wlbNpdidWellbore":1927,"wlbName":"6407/10-3","wlbHistory":"\r\n\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 6407/10-3 is located ca 15 km south\r\nof the Njord Field. The primary target of the well was to test Upper Jurassic\r\ntransgressive sandstone (Draugen analogue). Lower Jurassic to Upper Triassic\r\nsandstone was a possible secondary target. In summary, the main objectives for\r\ndrilling the well 6407/10-3 were: to test the oil potential of Upper Jurassic\r\ntransgressive sand; to test reservoir quality and hydrocarbon potential of the\r\ndipping pre-Jurassic reflectors; to penetrate the deep basement reflectors and\r\ntest reservoir quality in order to prepare area for relinquishment.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 6407/10-3 was spudded with the\r\nsemi-submersible installation Transocean 8 on 29 May 1992 and drilled to TD at\r\n2973 m in the Triassic Red Beds. The well was drilled with seawater and hi-vis\r\npills down to 907 m and with KCl/PHPA mud from 907 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe Upper Jurassic Viking Group was\r\nencountered at 1806 m and consisted of claystone characteristic of the Spekk\r\nFormation down to the Triassic section at 1827 m. From 1827 m to 1850 m\r\nTriassic Grey Beds were penetrated. From 1850 m to 2155 m undifferentiated Late\r\nto Middle Triassic Red Beds are present, followed by Carnian to Ladian Red Beds\r\nfrom 2155 m to 2555 m. Undifferentiated "red beds" continued to\r\n2958.5 m, were the bore passed into fractured granitic basement. Weak shows\r\nwere observed on cuttings from the Shetland and Cromer Knoll Groups (1518 m to\r\n1785 m). Fair shows were observed on a core and a sidewall core from 1827 m to\r\n1836 m in the Triassic Grey Beds. Two cores were cut, the first from 1830 m\r\nto1837 m in the Grey Beds, the second was a one-metre core at 2972 m at TD. No\r\nfluid samples were taken. The well was permanently abandoned on 27 June 1992 as\r\na dry hole.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was performed\u003c/p\u003e\r\n\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"806","properties":{"OBJECTID":806,"wlbNpdidWellbore":1928,"wlbName":"1/6-7","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 1/6-7 is located in the Feda Graben\r\nof the North Sea, approximately mid-way between the Albuskjell and Tommeliten\r\nGamma fields. It was drilled on the flank of a salt diapir. The primary\r\nobjective of the well was to test the hydrocarbon potential of Late Jurassic\r\nsandstones. Two secondary objectives were identified; to test for hydrocarbons\r\nin the Cretaceous Chalk and to test for the development and the hydrocarbon\r\npotential of Paleocene sands.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 1/6-7 was spudded with the\r\nsemi-submersible installation West Vanguard on 16 March 1992 and drilled to TD\r\nat 4995 m (5001 m logger's depth / 4925 m TVD). A 9 7/8" pilot hole was\r\ndrilled from 170 to 1007m prior to the 26" section to check for possible shallow\r\ngas at 311, 351, and 397 m. No shallow gas was seen. MWD check-shots inside the\r\n20" casing (azimuth unreliable) proved that the well had sidetracked in\r\nthe 26" hole. In the 12 1/4" hole a steerable assembly was run in\r\nhole to correct the course. This twisted off, leaving a fish at 3740 m. The\r\nwell was plugged back to 3550 m and the well was sidetracked from 3650 m. After\r\nthe sidetrack the azimuth stayed fairly constant in a northwest direction. The\r\ninclination, though, increased. In the 12 1/4" hole from 3515 m to 4329 m\r\nthe angle built from 3.73deg to 13.52deg. The angle kept building in the 8\r\n1/2" hole until a maximum MWD survey of 31.40deg at 4701m. At this depth\r\nthe bit was pulled out of the hole for an intermediate logging run and to\r\nchange the BHA to an angle dropping assembly. This assembly dropped the\r\ninclination to 24.7deg by TD. At 4878 m, in the top of Sandstone Unit II, a\r\nsalt water kick was taken. The well was drilled with seawater with viscous\r\npre-hydrated bentonite sweeps down to 1007 m, with","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"807","properties":{"OBJECTID":807,"wlbNpdidWellbore":1938,"wlbName":"25/2-15","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 25/2-15 is located in the southern\r\npart of block 25/2, and was designed to recognize the petroleum potential of\r\nthe so-called Jurassic Prospect 1. The main objective of the well was to\r\nexplore the Middle Jurassic Brent sandstones. An optional objective was Early\r\nJurassic Statfjord sandstones, depending on the petroleum results at the Brent\r\nlevel. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 25/2-15 was spudded with the\r\nsemi-submersible installation West Alpha on 14 November 1992 and drilled to TD\r\nat 3505 m in Middle Jurassic sediments of the Heather Formation. \u003c/p\u003e\r\n\r\n\u003cp\u003eAfter drilling to TD at 3505 m in the 12\r\n1/4" section the drill string was hung off with bit at 13 3/8" casing\r\nshoe, due to bad weather. A long period of bad weather followed with a total of\r\n170 hours WOW. On 13 January 1993, when reaming up the hole to set 9 5/8"\r\ncasing, a fire broke out in the port side engine room. As a consequence of this\r\nthree anchor chains were lost and the rig started to drift. The drill string\r\nwas sheared and the LMRP was disconnected. All unnecessary personnel were\r\nevacuated. The situation was brought under control, but due to the damage\r\noccurring in engine room, it was decided to substitute the rig, pull anchors\r\nand move the rig to Haugesund fjord. The well was drilled with seawater and\r\nhi-vis bentonite sweeps down to 198 m, with bentonite mud from 198 m to 1150 m,\r\nand with gypsum polymer mud treated with 5% polyglycerol from 1150 m to 3505 m.\u003c/p\u003e\r\n\r\n\u003cp\u003eAll geological results from the well are\r\ngiven in the 25/2-15 R2 history.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was suspended with the drill\r\nstring fallen in the hole and shear rams closed. The hole was full of 1.27 SG\r\nmud. West Alpha left location on 19 January 1993.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was performed in the\r\nwell.\u003c/p\u003e\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"808","properties":{"OBJECTID":808,"wlbNpdidWellbore":1940,"wlbName":"34/10-36","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 34/10-36 was the sixth well drilled\r\non the Gullfaks Sør structure. The objectives were to test the potential of\r\nIntra-Draupne Formation turbiditic sandstone, and to confirm the gas-oil\r\ncontact, the oil-water contact, and the pressure regime in the Brent Group.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 34/10-36 was spudded with\r\nthe semi-submersible installation Deepsea Bergen on 28 April 1992\u00A0 and drilled\r\nto TD at 3640 m in the Early Jurassic Cook Formation. A 9 7/8” pilot hole was drilled\r\nfrom surface to 859 m to check for shallow gas. The MWD indicated several sands\r\nbut all were water-filled. The well was drilled with seawater and CMC down to\r\n1071 m, with gypsum/polymer mud from 1071 m to 3010 m, and with\r\nAncotemp/bentonite from 3010 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe Draupne Formation consisted of shale with\r\nonly traces of sandstone stringers towards the base. The Brent Group, Tarbert\r\nFormation was encountered at 3361 m (3355.3 m TVD), 55 m deeper than prognosed.\r\nIt was oil-bearing down to the OWC at 3377.5 m (3371.9 m TVD). Shows were seen\r\ndown to 3397 m. The GOC was not penetrated in the well location. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThree cores were cut in the well. Core 1 was\r\ncut from 3029 to 3054 m in the Draupne Formation. Cores 2 and 3 were cut in the\r\nTarbert Formation from 3363 m to 3417 m. The core shifts for cores 1, 2 and 3\r\nwere 3.0 m, 2.3 m and 2.3 m, respectively. One segregated sample was taken at\r\n3363.8 m. The 2 3/4 gallon chamber contained 3.5 litres of oil, 3.5 litres of\r\nmud filtrate and 0.22 m3 gas. No CO2 or H2S was detected from this sample\r\nchamber.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was permanently abandoned on 13\r\nJuly 1992 as an oil appraisal well.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBod","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"809","properties":{"OBJECTID":809,"wlbNpdidWellbore":1941,"wlbName":"34/8-7","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 34/8-7 is\r\nlocated on the western flank of the Tampen Spur and is situated approximately\r\n7.4 kilometres due east of well 34/8-4S, in the Visund prospect. This was the\r\nthird exploration well to be drilled in the licence area. The primary objective\r\nof well 34/8-7 was to test the Jurassic Brent Group and Statfjord Formation in\r\nthe hanging wall of the Visund Fault. The secondary objectives were to\r\nestablish a good seismic to well correlation and to fulfil licence obligations.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eExploration well\r\n34/8-7 was spudded with the semi-submersible rig "Polar Pioneer" on\r\n21 March 1992 and drilled to TD at 5460 m in the Triassic Hegre Group. The well\r\nwas drilled with spud mud down to 1444 m and with KCl/PHPA/Polymer mud from 1444\r\nm to 3288 m. From 3288 m the mud system was gradually changed to a HTHP (high\r\ntemperature stable polymers) mud. Still, towards TD of the well it was evident\r\nthat some of the chemical/polymers was decomposing and forming carbonates.\u003c/p\u003e\r\n\r\n\u003cp\u003eConglomeratic\r\ndensity flow deposits (Intra Draupne Formation sandstone) were found in the\r\nupper part of the Draupne Formation. From a gross thickness of 134.5m, 5.75m of\r\nnet sand were identified of which 5.25m were regarded as net pay. An average\r\nporosity value 9.4% and average Sw of 50.1% were computed for the pay section.\r\nA core cut in the Intra Draupne sandstone gave 5.2 % core porosity on average.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe primary\r\nobjective Brent Group was encountered at 4632.5 m. The entire Brent Group was\r\ninterpreted as being gas bearing. From a gross thickness of 134.5m, 36.5m of\r\nnet sand were recognised with 36.5m of net pay. An average porosity of 9.8% and\r\naverage Sw of 30.4% were determined. A core cut in the Brent Group, gave an\r\naverage porosity of 9.9 %. The sandy member of Cook Formation was found to be\r\ngas bearing, but poor reservoir properties reduced the net pay to only 2.0 m\r\nwith an average porosity of 8.3 % and average Sw of 36.1 %.\u003c/p\u003e\r\n\r\n\u003cp\u003eNo","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"810","properties":{"OBJECTID":810,"wlbNpdidWellbore":1949,"wlbName":"25/6-2","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well 25/6-2 is located in the\r\nsouthern part of block 25/6, approximately 175 km Northwest of Stavanger on the\r\nnorthern part of the Utsira High. Utsira High forms the southern part of\r\nwestern rim of the Horda Platform and lies between the South Viking Graben to\r\nthe west and Stord Basin to the east. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe main objectives for the well 25/6-2\r\nwere to test the hydrocarbon potential of the Paleocene Ty Formation in the\r\nDelta and Beta prospects and the extension of the Middle Jurassic Vestland Group\r\ndiscovery in well 25/6-1. The Ty Formation prospects were anticipated to\r\ncomprise of clastic, gravity fan deposits.\u00A0 The well location was in a position\r\nthat would test both a mapped simple closure at this level and a larger\r\nstratigraphic trap interpreted to be characterised by sands pinching out to the\r\nsouth.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well 25/6-2 was spudded with the\r\nsemi-submersible installation Treasure Saga the 26 April 1992 and drilled to TD\r\nat 2392 m in the Early Jurassic Drake formation. The well was drilled with\r\nseawater and gel down to 1046 m and with KCl mud from 1046 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe Nordland, Hordaland and Rogaland\r\nGroups consisted mainly of clays and claystones with minor sandstones. The\r\nCromer Knoll Group consisted of limestone interbedded with claystones and\r\nmarls, while the Viking Group consisted mainly of claystones as expected. The\r\ntops prognosed for the well were within the expected margin of error for the\r\nTop Balder and Top Shetland seismic markers.\u00A0 However, the depths prognosed for\r\nthe Top Ty Formation, base Cretaceous, top Vestland, and top Dunlin markers were\r\noff by as much as 65m.\u00A0 Therefore, the top of the Vestland Group was encountered 39.5 m\r\nbelow the oil water contact in the Vestland discovery at 25/6-1. No hydrocarbons\r\nwere encountered in any of the prospective intervals, and only one show was\r\ndescribed from a single cutting sample recovered from the Vestland Group. No cores\r\nwere cut and no fl","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"811","properties":{"OBJECTID":811,"wlbNpdidWellbore":1950,"wlbName":"30/3-5 S","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 30/3-5 S was drilled on the G\r\nprospect, which lies to the east of the Veslefrikk Field. The main target was\r\nthe Brent Group with Early Jurassic Statfjord Group as a secondary target. The\r\nwell was designed to be completed as an oil producer on the G prospect.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 30/3-5 S was spudded through slot 6\r\non the fixed installation Veslefrikk A on 1 May 1992 and drilled to TD at 4724\r\nm (3340 m TVD) in the Early Jurassic Statfjord Group. Severe doglegs and ledging\r\nin the well path created problems in the 24" section from 472 to 1409 m. An\r\nattempt to reach an additional target in the Statfjord Formation failed due to\r\nproblems with directional drilling. The well was drilled with gypsum/PAC mud\r\ndown to 2551 m and with oil based mud from 2551 m to TD. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe planned targets were reached. The top\r\nof the Brent Group was penetrated at 4050 m, 8 m vertically deeper than\r\nprognosed. As expected, a fully developed Brent Group was present in the well. Apart\r\nfrom the Amundsen Formation, which came in 3.5 m shallower than prognosed, the\r\nformation tops came in slightly deeper than prognosed. The well proved\r\nhydrocarbons in the Brent Group and in the Cook Formation of the Dunlin Group. Differential\r\npressure depletion was observed in some zones of the Brent Formation,\r\nattributed to communication with the main Veslefrikk Field which has been in\r\nproduction since 1989. The Statfjord Group had shows in the uppermost part. Rare,\r\nweak shows were seen in limestones and siltstones in the Shetland Group. No\r\nother shows were reported outside the reservoir section. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eFive cores were cut. Cores 1 to 3 were\r\ncut from 4060 to 4160 m in the Ness-Etive-Rannoch-Oseberg formations, core 4\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"812","properties":{"OBJECTID":812,"wlbNpdidWellbore":1956,"wlbName":"2/4-16 R","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThe licence area is located in a prolific\r\narea in the southern North Sea on the eastern margin of the Feda Graben. Well\r\n2/4-16 was drilled on the eastern margin of the Feda Graben North of the\r\nAlbuskjell and Ekofisk Fields in the North Sea. Geologically the area consists\r\nof three sub-platforms. These are separated by large NW-SE striking normal\r\nfaults down-faulted to the southwest and stepping down to the Feda Graben in\r\nthe southern part of the block. The 2/4-16 well is located in the centre of the\r\nlicence area on the same down faulted segment as the blowout wells 2/4-13, -14\r\nand -15. Well 2/4-16 was temporarily abandoned at 4996 m in the Middle Jurassic\r\nBryne formation due to operational problems. The main objective of well 2/4-16\r\nR was to penetrate the Middle Jurassic and through the Triassic sequence to\r\ntest for possible hydrocarbon bearing sandstone sequences. The plan was to\r\nsidetrack just below the 7 5/8" casing shoe at 4892 m and if operation\r\npermitted, to penetrate the complete Triassic sequence and terminate the well\r\nin the Zechstein Group evaporites. Planned TD for the well was 5190 + 60 m. If\r\nno signs of salt/anhydrite, the maximum TD of the well should be 5250 m.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 2/4-16 was re-entered (2/4-16 R)\r\nwith the semi-submersible installation Treasure Saga on 4 June 1992. The old\r\nhole was sidetracked between 4900 to 4930 m and drilled to 4973 m in the Middle\r\nJurassic Bryne Formation where the well was terminated due to extremely high\r\npore pressures in the range 2.16 - 2.17 EMW. One week was spent attempting to\r\nbleed off pressure with no success. Analysis of the bleed-off operation showed\r\nthat it was impossible to reduce the high pore pressure. As the source of the\r\nextreme pore pressure is of unknown origin it was decided to stop further\r\ndrilling and permanently abandon the well.\u003c/p\u003e\r\n\r\n\u003cp\u003eNo conventional logs for formation\r\nevaluation were run. No cores were cut and no wire line fluid samples take","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"813","properties":{"OBJECTID":813,"wlbNpdidWellbore":1967,"wlbName":"34/7-20","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eExploration well 34/7-20 is located\r\nbetween the Snorre and the Statfjord Nord Field on Tampen Spur in the Northern North Sea. The well is positioned up-dip on a gently west-dipping structure that\r\nincludes a supposed thin Late Jurassic sand interval. The primary objective was\r\nthis Late Jurassic sand in a pinch-out trap. A secondary objective was to test the\r\nBrent Group, and if water-bearing, make a pressure test in order to evaluate\r\npossible communication to the Vigdis West Field. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 34/7-20 was spudded with the\r\nsemi-submersible installation Treasure Saga on 18 July 1992 and drilled to TD at 3177 m in the Late Triassic Lunde Formation. The 12 1/4" section was\r\ndrilled with slow penetration rates, frequent wiper trips, and frequent change\r\nof drill bits. After a bit change, the new BHA went stuck at 2724 m while\r\nrunning in the hole, and had to be worked free with 110 tons overpull. The well\r\nwas drilled with spud mud down to 419 m, with gel mud from 419 m to 1220 m, and\r\nwith KCl mud from 1220 m to TD. Indications of shallow gas were seen at 557 -558\r\nm and at 620 - 621 m.\u003c/p\u003e\r\n\r\n\u003cp\u003eDown to Base Cretaceous the well\r\npenetrated mainly claystones. An exception to this was the sandy Utsira\r\nFormation between 961 and 1040 m. The Jurassic interval comprised the prognosed\r\nLate Jurassic sandstone and Heather Formation, the Middle Jurassic Brent Group\r\nand the Early Jurassic Dunlin Group. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe top of the primary target Late\r\nJurassic reservoir was penetrated at 2578 m, 7 meter shallower than prognosed. Only\r\n3 meter of Late Jurassic sand was penetrated and proved water bearing with oil-shows.\r\nThese were the only shows reported in the well.\u003c/p\u003e\r\n\r\n\u003cp\u003ePressure tests in the Brent and Viking\r\nGroups in well 34/7-20 indicated communication between the sandstones of the\r\nLate Jurassic and Brent Groups. These sandstone units are probably in contact\r\nfurther up-dip, which is, most likely, the explanation to why the well","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"814","properties":{"OBJECTID":814,"wlbNpdidWellbore":1969,"wlbName":"34/8-8","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 34/8-8 was drilled to appraise the N-1\r\nsegment of the 34/8-1 Visund discovery on Tampen Spur in the Northern North\r\nSea. The N-1 segment is estimated to contain approximately 30% of the resources\r\nin the Brent-North area. Confirmation of these resources was critical for\r\nreservoir management and production layout in future development plans. The\r\nprimary objectives of the well were thus to confirm the resources in the Brent\r\nGroup and to obtain data that could be used in reservoir engineering studies on\r\nimproved oil recovery. Secondary objectives were evaluations of the Statfjord\r\nFormation and the Lunde B/C Formation. The well design and location was chosen\r\nprimarily to evaluate the Brent target with respect to defining fluid contacts\r\nin clean sands, avoid faults, and penetrate as close as possible to the erosion\r\nedge of the top of the Brent Group.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 34/8-8 was spudded with\r\nthe semi-submersible installation Transocean 8 on 30 June 1992 and drilled to\r\nTD at 3625 m in the Late Triassic Lund Formation. After drilling to 1430 m in\r\nthe 12 1/4" section the drill string got stuck. 16.55 m of the BHA was\r\nleft in the hole and the hole was plugged back to 1354 m where a minor\r\ntechnical sidetrack was performed. After setting the 30" casing an\r\nindustry strike caused ca 5 days downtime. The well was drilled with spud mud\r\ndown to 1364 m, and with Anco 2000 glycol mud from 1364 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe Brent Group was encountered at 2921\r\nto 3077 m. It was oil bearing and wire line logs confirmed an OWC at 2971 m, while\r\nRFT pressure tests suggested a free water level between 2973.4 m and 2976.8 m. From\r\na gross Brent Group thickness of 156 m, a net pay thickness of 97 m was\r\nidentified. An average porosity of","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"815","properties":{"OBJECTID":815,"wlbNpdidWellbore":1970,"wlbName":"30/2-3","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 30/2-2 was drilled on the Huldra\r\nField in the North Sea.\u003c/span\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003cspan lang=EN-US\u003eThe\r\nobjective was \u003c/span\u003e\u003cspan lang=EN-GB\u003eto appraise the gas/condensate discovery\r\nin the Brent Group and reduce the gas-in-place estimates for the field.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 30/2-2 was spudded with\r\nthe semi-submersible installation Ross Isle on 11 June 1992\u00A0 and drilled to TD\r\nat 4325 m in the Early Jurassic Eiriksson Formation. A pilot hole was drilled\r\nto 520 m to check for shallow gas. No gas was detected. Drilling proceeded\r\nwithout significant problems. Tool sticking was common in the reservoir section\r\nduring logging runs. The well was drilled with seawater down to 209 m, with gel\r\nspud mud from 209 m to 1115 m, with gypsum/polymer mud from 1115 m to 2298 m,\r\nand with Ancotherm mud from 2298 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAlthough a well-defined Gas-Water-contact\r\nwas encountered in 30/2-3 at 3896 m, this was some 75 m shallower than the\r\npreviously deepest gas-down-to for well 30/2-2. This indicates that the Huldra\r\nField is more complex than previously thought. Good porosity and permeability\r\nwere encountered in all gas bearing intervals, reducing uncertainties regarding\r\nwell productivity. There were no shows above Brent reservoir level. Below the\r\nGWC weak shows on sandstone in the cores gradually diminished down to 3962 m\r\nwhere shows disappeared altogether.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eA total of 178.4 m core was recovered in\r\n17 cores, from 3749 m in the Heather Formation through all of the Brent Group\r\nand down to 3985 m at top Drake Formation. The core-to-log depth correction varied\r\nbetween -0.4 to +1.9 m. No wire line fluid samples were taken.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"816","properties":{"OBJECTID":816,"wlbNpdidWellbore":1972,"wlbName":"10/7-1","wlbHistory":"\r\n\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 10/7-1 is located at the\r\nsoutheastern end of the Egersund Basin in the North Sea. The objective of the\r\nwell was to test the Tott prospect, a faulted anticline over a salt wall. The\r\nMiddle Jurassic Bryne formation was the primary objective. A thin Sandnes\r\nformation sandstone overlying the Bryne was interpreted to be possible at the\r\ndrilled location.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 10/7-1 was spudded with the\r\nsemi-submersible installation Sonat Arcade Frontier on 28 June 1992 and drilled\r\nto TD at 1890 m in the Late Permian Zechstein Group. The well was drilled with\r\nseawater and gel down to 793 m and with KCl/polymer mud from 793 m to TD. \u003c/p\u003e\r\n\r\n\u003cp\u003eGood reservoir quality sandstones were\r\nencountered in both the Sandnes and Bryne formations of the Vestland group. The\r\ntop of the Sandnes formation was penetrated at 1539 m; top of the Bryne at 1632\r\nm. Total thickness of the Vestland group is 297 m. From drill cuttings, fair to\r\ngood visible porosity was observed in fine to coarse-grained sandstones\r\nthroughout the Vestland group. Reservoir quality is good, with a net sand/gross\r\nthickness ratio of 54.5% using a 12% porosity cut-off. Using the same cut-off\r\nvalue the average porosity of the reservoir sandstones in the Vestland group is\r\n23.3%. Bathonian age sediments (Bryne Formation) rested directly on Late\r\nPermian Zechstein salt at 1836 m. Occasional, spotty shows were observed in\r\ncuttings from the Sandnes and Bryne Formations. These marginal shows were\r\ninterpreted to be sourced from in-situ carbonaceous material and not as\r\nmigrated hydrocarbons. Analysis of the wire line logs and wire line pressure\r\ndata clearly indicated that the sandstones of the Vestland group were water\r\nbearing. Organic geochemical analyses showed Total Organic Carbon (TOC) from\r\n1.0 to 3.19 % and Hydrogen Index (HI) from 79 to 224 mg HC/g TOC in the Late\r\nJurassic shales, which was classified as a poor oil and gas source. Associated\r\nwith coals in the Vestland g","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"817","properties":{"OBJECTID":817,"wlbNpdidWellbore":1973,"wlbName":"6506/11-3","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well 6506/11-3 is located in the\r\nHaltenbanken region, north west of the Smørbukk area. The objectives of well\r\n6506/11-3 were: to prove oil in the Lysing, Lange (Cretaceous) and the Rogn\r\n(Jurassic) Formation; to test the hydrocarbon potential of the Nise Formation\r\nand the Åre Formation; and to penetrate the Upper Triassic and test the\r\nreservoir potential in order to prepare for relinquishment.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 6506/11-3 was spudded with the\r\nsemi-submersible installation Ross Rig on 8 July 1992 and drilled to TD at 4350\r\nm in the Middle Jurassic Not Formation. The well was drilled with seawater and\r\nhi-vis pills down to 1020 m, with Gypsum/PAC-Polymer mud from 1020 m to 2020 m,\r\nwith Gypsum/PAC/Thermopol/Ancotemp mud from 2020 m to 3717 m, and with\r\nAncotherm mud from 3717 m to TD. Due to high pressure the well was terminated\r\nat a shallower depth than prognosis\u003c/p\u003e\r\n\r\n\u003cp\u003eTop Nise Formation was encountered at\r\n2357 m and proved to be 196 m thick. It was predominantly Clay/Claystone with\r\nsome thin sandstone layers, mostly in the upper part. The Lysing Formation was\r\ntested and produced water with minor amounts of gas. Only 2 m Spekk Formation\r\nwas encountered and the Rogn Formation was not developed. Sandstones of the\r\nJurassic Garn Formation were water bearing. Shows were recorded in the Lysing\r\nand Garn Formation. \u003c/p\u003e\r\n\r\n\u003cp\u003ePost-well geochemical screening of cores\r\nshowed shales of good potential in the interval 3920 m to 3990 m across the\r\nCenomanian ? Turonian in the Lange Formation. This may possibly be seen as an\r\nequivalent to the Blodøks Formation in the North Sea. \u003c/p\u003e\r\n\r\n\u003cp\u003eTen cores were cut in the well. Core 1\r\nwas cut from 3143.5 m to 3170.5 m in the Lysing Formation. Cores 2, 3, and 4\r\nwere cut in the interval 3919 m to 3945.6 m in Upper Cenomanian ? Turonian\r\nsediments of the Lange Formation. Cores 5, 6, and 7 were cut in the interval\r\n3976 m to 4003 m in Albian to Cenomanian sediments of the Lange Formation.\r\nCores 8, 9, ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"818","properties":{"OBJECTID":818,"wlbNpdidWellbore":1974,"wlbName":"6407/9-8","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 6407/9-8 was drilled on the\r\nHusmus East structure, situated east of the Draugen Field on the edge of the\r\nTrøndelag Platform on the Mid Norwegian Continental Shelf. The principal\r\nobjective of the well was to test the hydrocarbon potential of the Late\r\nJurassic Rogn Formation in a dip closure trap. Secondary objective was to test\r\nthe potential for gas storage in the Rogn Formation and in the middle Jurassic\r\nGarn Formation. The well was also drilled to acquire additional stratigraphic\r\ninformation on the reservoir development of the Middle and Early Jurassic Ile\r\nand Tilje Formation.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 6407/9-8 was spudded with the\r\nsemi-submersible installation West Vanguard on 14 August 1992 and drilled to TD\r\nat 2126 m in the Early Jurassic Tilje Formation. Operations went without\r\nsignificant problems. The well was drilled with seawater and bentonite down to\r\n1120 m, with polymer/gypsum mud from 1120 m to 1582 m, and with KCl/polymer mud\r\nfrom 1582 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eNo potential reservoir zones were found\r\nabove the Viking Group, which was penetrated from 1606.5 m to 1730 m. The Rogn\r\nFormation vas poorly developed as a thin (<1 m), well-cemented silty to very\r\nfine sandstone facies with low porosity and permeability. A well-developed Garn\r\nFormation in a sand facies vas encountered, with high porosities and\r\npermeabilities. The well vas terminated in sandstone of the Tilje Formation\r\nafter penetration of Ile Formation sandstone. Both the Garn Formation and the\r\nIle Formations appeared to be suitable for gas injection. The well was entirely\r\nwater wet all through. This was evident from electrical logs, pressure\r\ngradients, and lack of shows on cores and cuttings. Post-well geochemical\r\nanalyses of cores and cuttings confirmed general lack of migrated hydrocarbons.\r\nA total of seven cores were cut in the well with 105.95 m recovered. Cores 1 to\r\n5 were cut from 1605 m to 1685 m in the Spekk and Rogn Formations. Cores 6 and\r\n7 ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"819","properties":{"OBJECTID":819,"wlbNpdidWellbore":1978,"wlbName":"15/12-9 S","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 15/12-9 S was drilled on the Varg\r\nField in the North Sea. The Varg Field reservoir is in Upper Jurassic sandstones\r\nat a depth of approximately 2700 metres. The Varg Field is segmented and\r\nincludes several isolated compartments with varying reservoir properties. The\r\nwell was drilled from a location near to the Varg A and Petrojarl A production\r\ninstallations and targeted a southern compartment in the Varg structure. The\r\nobjective for the well was to prove hydrocarbons in Late Oxfordian sandstone\r\nand to reduce the uncertainty in the reserve estimate for this part of the Varg\r\nField.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 15/12-9 S was spudded with\r\nthe semi-submersible installation Deepsea Bergen on 17 July 1992 and drilled to\r\nTD at 3848 m (3213 m TVD) in the Triassic Skagerrak Formation. The well was\r\ndrilled deviated from 623 m with a sail angle of ca 56 ° and then vertical\r\nagain from ca 2400 m TVD through the target reservoir to TD. The well was\r\ndrilled with seawater down to 620 m, with KCl/polymer mud from 620 mto 3226 m,\r\nand with Ancotemp/bentonite mud from 3226 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well penetrated top reservoir, the\r\nOxfordian sandstones, at 3385 m (2750 m TVD). The reservoir was oil-bearing\r\ndown to a well-defined  OWC at 3501.5 m (2867.0 m TVD). Seven cores were cut with 100% recovery. Core 1\r\nto 6 were cut in the interval 3689 m to 3555 m and core 7 was cut from 3649.5 m\r\nto 3668.0 m. The core to log depth shift was -2.45 m for core 7; for the other\r\ncores the core depth was equal to the logger’s depth. Two segregated FMT oil samples were taken at 3498 m. Oil shows continued down to 3545m\r\n\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well is classified an oil appraisal\r\nwell. It was suspended on 8 October 1992 and was lat","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"820","properties":{"OBJECTID":820,"wlbNpdidWellbore":1979,"wlbName":"35/11-7","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThe 35/11-7 well is located in the\r\nsoutheastern part of the block, 2.5 kilometres east of the 35/11-4 discovery.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe primary objective of the well was the\r\nmiddle Jurassic Brent Group and the secondary objective was the Middle Jurassic\r\nFensfjord Formation. A tertiary objective was the Late Jurassic Sognefjord\r\nFormation.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 35/11-7 was spudded with the\r\nsemi submersible installation West Delta on 23 July 1992 and drilled to TD at\r\n2895 m in the Early Jurassic Statfjord Formation. Operations went smoothly with\r\nlittle downtime. The well was drilled with seawater and viscous pills down to\r\n966 m and with KCl/PHPA/PHB/PAC mud from 966 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eTraces of oil were seen in reservoir\r\nquality sandstone units within the Paleocene Lista Formation. No FMT samples\r\nwere taken and no detailed petrophysical analysis was carried out at this\r\nlevel. Good hydrocarbon bearing sandstones were found in the Late Jurassic\r\nSognefjord Formation from 1796 m. From FMT and log data the gas-oil contact is\r\nat 1800.5 m and the oil-water contact at 1851.5 m with a gross hydrocarbon\r\ncolumn of 31.7 m. The Middle Jurassic Fensfjord Formation was found to be water\r\nwet with no shows. The Brent Group from 2423.5 m has a gross hydrocarbon column\r\nof 58.1 m. From FMT and petrophysical analysis a gas-oil contact is present at\r\n2469.9 m and an oil-water contact at 2504.8 m. A total of eleven cores were cut\r\nin the Late and Middle Jurassic reservoirs. Five consecutive cores were taken\r\nin the Sognefjord Formation with 93 m cut and 95% recovered. Six cores were cut\r\nin the Brent Group (Ness through to Oseberg Formations), with 113 m cut and\r\n98.8 % recovered. FMT measurements indicate moderate to good permeabilities in\r\nthe Sognefjord Formation and Brent Groups. Eight segregated samples were taken,\r\nproving gas and oil in the Sognefjord Formation and gas and condensate in the\r\nBrent Group.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 1","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"821","properties":{"OBJECTID":821,"wlbNpdidWellbore":1986,"wlbName":"25/8-4","wlbHistory":"\r\n\r\n\r\n\r\n\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 25/8-4 was drilled o the Utsira\r\nHigh, in the vicinity of the Balder Field area in the North Sea. The main\r\nobjective was to test the hydrocarbon potential of the Paleocene sand in the\r\nHedila structure, a seismic mounded structure within the prospect area. The\r\nlocation of the well was chosen in an area were thick sands were expected to be\r\nfound in a high structural position. Additional targets were additional younger\r\nsand development in the Lista and Sele Formation.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 25/8-4 was spudded with the\r\nsemi-submersible installation Vildkat Explorer on 25 July 1992 and drilled to\r\nTD at 1891 m in the Late Cretaceous Hod Formation. No significant problems were\r\nencountered during operations. The well was drilled with spud mud down to 241 m\r\nand with polymer mud from 241 m to TD. No shallow gas was observed.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe Lista Formation was encountered at\r\n1710 m. A sequence of thin Heimdal Formation injection sands was recognised in\r\nthe Lista Formation in the interval down to 1780 m where a 50 m thick massive Heimdal\r\nFormation was encountered. In total these injection sands made up 5.9 m net\r\nsand, which was all hydrocarbon bearing. Average porosity in this net was 32.0%\r\nwith an average Sw of 10%. The main Heimdal Formation was found mainly water\r\nwet, with only a 1.5 m oil column from the top and down to an OWC at 1781.5 m\r\n(1756.5 m TVD MSL). Average porosity in the main Heimdal Formation was 33.9%. Oil\r\nshows in the Paleocene sandstones started to appear in top Balder Formation at\r\n1670 m and ended in the OWC in the Heimdal sandstone at 1782 m. In addition, poor\r\nshows were observed on limestone over the interval 1841 m - 1852 m in the\r\nEkofisk Formation.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003e","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"822","properties":{"OBJECTID":822,"wlbNpdidWellbore":1987,"wlbName":"7316/5-1","wlbHistory":"\r\n\r\n\r\n\r\n\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 7316/5-1 is located in the\r\nVestbakken Volcanic Province of Bjørnøya West area. The well is located about\r\n150 km south Southwest of Bjørnøya, and about 150 km North-west of well\r\n7219/9-1 which was used for correlation purposes.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe Primary objective of the well was the\r\npotential of Tertiary prospects at lower Oligocene and upper Eocene levels. A\r\nsecondary objective was to undertake a sampling and coring programme to provide\r\nimproved stratigraphical control in the area.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 7316/5-1 was spudded with the semi\r\nsubmersible installation Polar Pioneer 21 July 1992 and drilled to TD at 4027 m\r\nin the Late Cretaceous Nygrunnen Group. The first hole was drilled to 906 m\r\nwhere it had to be plugged and abandoned due to gas influx and lost\r\ncirculation. The rig was moved 43.4 m and the well was re-spudded on 5 August.\r\nOn the second attempt, an 8-1/2" pilot hole was drilled to 613 m. A\r\ndrilling break with associated gas production was observed at 606 m and a cement\r\nplug was set over the interval 540 m to 597 m. The well was drilled with spud\r\nmud down to 921 m, with KCl / PHPA polymer mud from 921 m to 3800 m. From 3800\r\nm to TD KCl was allowed to deplete naturally and the system was slowly\r\nconverted to a higher temperature stable mud.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe Uppermost Sandstone of the Eocene\r\nSotbakken Group B2 Member was encountered from 1340 m to 1383 m, and was\r\nconsidered to be gas bearing over the interval 1340 -1358.5 m. From a gross\r\nthickness of 43.0 m, a total net pay thickness of 9.75 m was calculated, giving\r\na net/gross ratio of 0.23. Average porosity of 28.2% and average Sw of 35.9%\r\nwas computed in the pay zone. A second sandstone was encountered from 1442 m to\r\n1469 m in the Sotbakken Group B2 Member. Gross thickness of this Sand was 27.0\r\nm, with average porosity of 32,1 %. It proved to be entirely water wet.\u003c/p\u003e\r\n\r\n\u003cp\u003eNumerous igneous intrusions were\r\npenetrated below 2976 m (Middle to Earl","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"823","properties":{"OBJECTID":823,"wlbNpdidWellbore":1988,"wlbName":"31/2-18","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThe purpose of well 31/2-18 was to appraise the structure\r\nand oil bearing potential of a fault block in the northern part of the Troll\r\nWest Gas province (TWGP). The objectives for drilling well 31/2-18 were to\r\nevaluate the structure for future development of oil producing wells in the\r\nTWGP-North area, and to determine the degree of development required to\r\nefficiently develop the oil reservoir in the TWGP-North area. Well 31/2-18A was\r\ndrilled as a pre-planned sidetrack to Well 31/2-18 in order to evaluate the\r\nhydrocarbon potential of the Krossfjord Formation. The primary objective of the\r\nsidetrack was to evaluate a seismic anomaly, or "flat spot" which had\r\nbeen identified in the Krossfjord Formation. The location of the anomaly was situated\r\n240 m to the northeast in an up thrown block, adjacent to the original well.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eAppraisal well 31/2-18 was spudded with\r\nthe semi-submersible installation "Treasure Saga" on 15 September\r\n1992, and drilled to a total depth of 1711 m in the Middle Jurassic Fensfjord\r\nFormation. The well was drilled with seawater and hi-vis pills down to 940 m\r\nand with KCl/Polymer mud from 940 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003ePalaeocene sand was encountered below\r\nbase Våle Formation, from 1519.9 m to 1528.8 m. This sand is in direct contact\r\nwith the underlying Late Jurassic Sognefjord Formation, which was encountered\r\nover the interval 1528.8 m - 1642.7 m. Gas was proven all through these sands\r\nfrom top of the Palaeocene sand down to 1571.2 m in the Sognefjord Formation. A\r\nthin oil leg was identified, with an oil-water contact at 1582.0 m. Sixteen\r\ngood RFT pressure measurements, including segregated samples at 1575 m and 1582\r\nm, were taken in one run over the interval 1522 m & 1689.5 m. The interval\r\nfrom 1498 m to 1678.5 m (Lower Rogaland Group including the Palaeocene sand,\r\nSognefjord Formation, and Heather Formation) was cored in twelve cores with 86\r\n100 % recovery. \u003c/p\u003e\r\n\r\n\u003cp\u003eAfter running wire line lo","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"824","properties":{"OBJECTID":824,"wlbNpdidWellbore":1989,"wlbName":"30/9-B-18","wlbHistory":"\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 30/9-B-18 was drilled as a\r\ndevelopment well on the 30/9-1 Oseberg Discovery in the North Sea. It was\r\ndrilled as a penetration well prior to the horizontal well 30/9-B-18 A. The\r\nobjective was to accurately locate the oil/water contact in the Oseberg Formation\r\nand to give structural information and exact target depth for the horizontal\r\nsection of the production well 30/9-B-18 A. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe NSO-1 geochemical standard oil was\r\nproduced from 30/9-B-18 A.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eDevelopment well 30/9-B-18 was spudded on\r\n10 June 1992. It was drilled from the Oseberg B platform   to TD at 3980 m\r\n(2814 m TVD) m in the Early Jurassic Drake Formation. The target of the well\r\nwas on the Oseberg Alpha Structure approximately 2.5 km south-east of the\r\nOseberg B platform. Serious hole cleaning problems were evident throughout the\r\n12 1/4" section, causing a sidetrack from 1448 m. The well was drilled\r\nwith spud mud down to 1155 m, with ANCO 2000 mud from 1155 to 3342 m, and with\r\noil based Safemul mud from 3342 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well drilled through a 121 metres\r\nvertical section of the Brent Group, which is 10 metres more than prognosed,\r\nand the oil-water contact was established at 3878 m MD (2767 m TVD). Good shows\r\nwere observed on the cores from the Oseberg Formation, otherwise no shows\r\ndescriptions were reported from the well. RFT pressure points proved an 11 bar\r\ndepleted oil gradient compared to the initial Oseberg-Rannoch-Etive gradient in\r\nthe Alpha structure.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eTwo cores were cut in succession from\r\n3859 to 3903 m in the Oseberg Formation. The core-log depth shift is +2 m for\r\nboth cores. The RFT was run on wireline to record pressure points in the","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"825","properties":{"OBJECTID":825,"wlbNpdidWellbore":1990,"wlbName":"6407/9-9","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 6407/9-9 is\r\nlocated on the western edge of the Trøndelag Platform in PL093, some 7 km\r\nNorthwest of the Draugen Field. It was drilled to test the hydrocarbon\r\npotential of the Middle Jurassic Ile and Tilje Formations in the "Hasselmus"\r\nprospect. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eExploration well\r\n6407/9-9 was spudded on 22 June with the semi-submersible installation\r\n"Mærsk Jutlander" and drilled to 1930 m where the bottom hole\r\nassembly was lost due to differential sticking. A technical sidetrack, 6407/9-9-T2,\r\nwas made. The sidetrack was kicked off from 1618 m in the original hole and\r\ndrilled to a total depth of 1920 m in sandstones of the Early Jurassic Tilje\r\nFormation. The well was drilled with seawater and hi-vis bentonite pills down\r\nto 1065 m and with "BARASILC" sodium silicate mud from 1065 m to TD.\r\nThe well found a 16 m gas column and a 6.8 m oil column in the Ile / Ror\r\nFormations with the oil-water contact at 1748.8 m. The reservoir had good\r\nporosities. Quality PVT oil and gas samples were taken both from the gas and\r\nthe oil leg (1736.1 m and 1746.1 m, respectively). No conventional cores were\r\ncut. The well was plugged and abandoned on 6 July 1999 as an oil and gas\r\ndiscovery. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting \u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test\r\nwas performed. \u003c/p\u003e\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"826","properties":{"OBJECTID":826,"wlbNpdidWellbore":2015,"wlbName":"30/10-7","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThe exploration well 30/10-7 was\r\ndedicated to explore the hydrocarbon potential of the Paleocene Hermod\r\nFormation.\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 30/10-7 is located in the\r\ncentral-northern part of block 30/10, and the Paleocene structure forms a\r\nmoundy/domal feature, with minor normal faults to the east and west of the well\r\nlocation. TD was planned at 2613 m in the Late Cretaceous Hardråde Formation.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well 30/10-7 was spudded 8 September\r\nby the semi-submersible installation Maersk Jutlander and drilled to TD at 2612\r\nm in the Late Cretaceous Hardråde Formation. The well was drilled with seawater\r\nand hi-vis pills down to 1270 m and with Gyp / Polymer mud from 1270 m to TD.\r\nThe well encountered sands with very good reservoir characteristics both in the\r\nHermod Formation and in the Heimdal Formation, but the reservoirs were water\r\nbearing. In the entire well bore no shows of any kind was observed. Two cores\r\nwere cut from 2207 m to 2227 m and recovered sands and mudstone from the Hermod\r\nand Sele Formations. No fluid samples were taken.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 17\r\nOctober 1992 as a dry hole.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was performed\u003c/p\u003e\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"827","properties":{"OBJECTID":827,"wlbNpdidWellbore":2016,"wlbName":"30/9-B-18 A","wlbHistory":"\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 30/9-B-18 A is a production\r\nside-track from observation well 30/9-B-18 on the 30/9-1 Oseberg Discovery in\r\nthe North Sea. The main objective for Well 30/9-B-18A was oil production from a\r\nplanned 1200 metres horizontal section in the Oseberg, Etive and Lower Ness Formations.\r\n\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003ca name=\"_Hlk144127129\"\u003e\u003cspan lang=EN-GB\u003eThe NSO-1\r\ngeochemical standard oil was produced from 30/9-B-18 A.\u003c/span\u003e\u003c/a\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eDevelopment well 30/9-B-18 A was kicked\r\noff at 3344 m in well 30/9-B-18  on 26 September 1992. It was drilled from the\r\nOseberg B platform to TD at 4982 m (2761 m TVD) m in the Middle Jurassic Ness\r\nFormation. The target of the well was on the Oseberg Alpha Structure\r\napproximately 3 km south-east of the Oseberg B platform. It was drilled horizontally\r\n(between 88  and 93  deviation) from ca 3850 m in the Oseberg Formation To TD\r\nat 4982 m in the Ness Formation. The well was drilled with oil based Safemul\r\nmud from kick-off  to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eTotal drilled length of Oseberg, Etive\r\nand Lower Ness in the horizontal well is ca 1130 m, in line with the prognosed\r\n1200 metres. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo cores were cut in this well. No wireline\r\npressures were taken, and no wireline fluid sample was taken. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was completed as a producer on 8\r\nDecember 1992.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eTesting\u003c/span\u003e\u003c/b\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was completed with 15\r\nperforation intervals between 3831 m and 4912 m (2762.2 m TVD and 2759.5 m TVD)\r\nin the horizontal sections in the lower Ness and Oseberg-Rannoch-Etive (ORE)\r\nformations. Production testing measured flow rat","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"828","properties":{"OBJECTID":828,"wlbNpdidWellbore":2018,"wlbName":"7122/2-1","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 7122/2-1 is located on the northern\r\nperiphery of the Hammerfest Basin towards the Loppa High. The primary objective\r\nof the well was to test the potential of Valanginian and Hauterivian\r\nstratigraphic prospect 7122/2, 3-A. Additional objectives were to undertake a\r\ncoring and sampling programme necessary for evaluation of the hydrocarbon\r\npotential of the 7122/2 3-A prospect and the surrounding area; to obtain an\r\nimproved understanding of the reservoir potential, source rock development and\r\nmaturity of the area; and to obtain better stratigraphic and velocity control.\r\nPlanned TD was at least 50 m into the Middle Jurassic Stø Formation, and if\r\nhydrocarbons were encountered, to drill on until shows ceased.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 7122/2-1 was spudded with\r\nthe semi-submersible rig Polar Pioneer on 7 October 1992 and drilled to TD at\r\n2120 m in the Middle Jurassic Stø Formation. The drill string stuck at 669 m in\r\nthe 24" section and a technical sidetrack was performed. Apart from this\r\ndrilling operations went on without significant problems. The well was drilled\r\nwith seawater and hi-vis pills down to 734 m and with KCl/PHPA/polymer mud from\r\n734 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe primary target, The Knurr Formation,\r\nwas encountered from 1831.5m to 1954.5m and was water bearing. It consisted of\r\nmassive sandstone sequence. Average horizontal permeability from cores was\r\n636.3 mD. The secondary target, the Stø Formation, was also water bearing. Top\r\nStø Formation was penetrated at 2067.5 m.\u003c/p\u003e\r\n\r\n\u003cp\u003eOrganic geochemical analyses showed that\r\nthe maturity of the penetrated sections in well 7122/2-1 range from\r\nimmature/early mature in the Lower Cretaceous (800 m / %Ro ca 0.47) to peak\r\nmature in the Lower Jurassic (2120 m / %Ro ca 0.75). Both source rock sections,\r\nthe Middle Barremian to Early Aptian Kolje Formation and the Late Jurassic\r\nHekkingen Formation are mature with respect to oil generation. The remaining\r\nhydrocarbon generation poten","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"829","properties":{"OBJECTID":829,"wlbNpdidWellbore":2026,"wlbName":"34/7-21","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eExploration well 34/7-21 was drilled the\r\nsouth-western part of block 34/7 on Tampen Spur, on the H-prospect northwest of\r\nthe Tordis Field. The main objective was to test the hydrocarbon prospectivity\r\nwithin the Late Jurassic (Viking Group) interval. The target was a Late\r\nJurassic sand wedge, truncated in the up-dip direction towards the east by the\r\nBase Cretaceous Unconformity. Sufficient amounts of reservoir sand were\r\nconditioned by erosion and re-sedimentation from the underlying Middle Jurassic\r\nBrent Group, which is progressively truncated up-dip in the same direction. The\r\nsecondary objective was to test the Paleocene in which an oil discovery had\r\nbeen made in well 34/7-18.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 34/7-21 was spudded with the semi-submersible\r\ninstallation Treasure Saga on 19 October 1992 and drilled to TD at 3015 m in\r\nthe Early Jurassic Drake Formation. Tight and sticky formation was reported in\r\nthe 12 1/4" section, but no significant technical problems occurred in the\r\noperations. Based on the site survey, possible shallow gas was predicted at\r\n298, 548 and 612 m. The MWD confirmed a gas bearing sand at 541 m - 548 m. A\r\nflow check proved negative. The well was drilled with spud mud down to 1113 m\r\nand with KCl polymer mud from 1113 m to TD. \u003c/p\u003e\r\n\r\n\u003cp\u003eIn the Nordland, Hordaland, and Upper\r\nRogaland Groups, the well penetrated mainly clay/claystone with minor sand,\r\nexcept for the sandy Utsira Formation between 929-1040 m. At the base of the Rogaland\r\nGroup, the Lista Formation sandstone was encountered and proven dry, but with\r\nshows. In the Shetland and the condensed Cromer Knoll Group, claystone with\r\nlimestone beds and massive marls/limestones were penetrated, respectively. A\r\nhydrocarbon-bearing interval was proven in a sand in the Cromer Knoll at 2498-2501\r\nm. The top of the Late Jurassic reservoir was reached at 2508 m, which was 29 m\r\nshallower than prognosed. Within the Draupne Formation, two separate oil\r\nbearing sandstone i","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"830","properties":{"OBJECTID":830,"wlbNpdidWellbore":2029,"wlbName":"34/8-9 S","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 34/8-9 S is located on the\r\nA-structure on the Visund Field. This is a NNE-SSW oriented elongated fault\r\nblock with the Pre-Cretaceous strata dipping towards WNW. The A-Central fault\r\ndivides the A-structure into the A-North and A-South compartments. Well 34/8-9\r\nS was drilled on the southern part of the A-South compartment. The primary\r\nobjective was to establish the inferred OWC at 3100m TVD and confirm the\r\npressure regime in the Statfjord and Amundsen Formations. The secondary objective\r\nwas to determine the hydrocarbon potential of the Cook Formation in the\r\nstructure. The well was designed deviated in order that both objectives could\r\nbe fully evaluated. Furthermore the spud location of the well was chosen so\r\nthat an optimal, up-dip, sidetrack could be drilled in order to appraise the\r\nLunde A-south gas condensate discovery.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 34/8-9 S was spudded with\r\nthe semi-submersible installation West Delta on 25 October 1992. The first\r\n36" top hole was abandoned because after casing was set due to drill\r\nstring lost in hole. The rig was moved 28 m from first spud location and\r\nre-spudded. The rig downtime for this well amounted to 30% of the total rig\r\ntime. Most of this was drilling equipment repairs and fishing for equipment,\r\nbut no single event had any serious consequence for the personnel or the well\r\nobjectives. The well was drilled to TD at 3530 m in the Late Triassic Lunde\r\nFormation. The well was drilled with seawater and hi-vis pills down to 1698 m\r\nand with HF-plus KCl/polymer mud from 1698 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe Viking Group, Draupne Formation was\r\nencountered at 2903. 5 m (2873.5 m TVD). Weak source rock shows were recorded\r\nin these shales. The Brent Group was encountered from 2922.5 m to 2983.5 m\r","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"831","properties":{"OBJECTID":831,"wlbNpdidWellbore":2031,"wlbName":"7219/8-1 S","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eExploration well 7219/8-1 S is located in\r\nthe Bjørnøya Sør area west of the Veslemøy High. This was a new geological\r\nprovince and hence the well was a true wildcat. The well was drilled up-dip of\r\na rotated fault block at Late to Middle Jurassic level. The primary purpose of\r\nthe well 7219/8-1 S was to test the Middle Jurassic Stø Formation. A secondary\r\nobjective was to test possible sandstone in Late Jurassic Hekkingen Formation,\r\nand finally, to test possible sandstone in a defined stratigraphic trap in the\r\nEarly Cretaceous sequences.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 7219/8-1 S was spudded with the semi\r\nsubmersible installation Ross Rig on 5 October 1992 and drilled to TD at 4611.5\r\nm, 91 m into the Early - Middle Jurassic Stø Formation. The well was drilled\r\ndeviated towards northwest with a direction of approximately 294 degrees with\r\napproximately 22 degrees inclination. Kick off point was at 1396 m. No shallow\r\ngas was identified. The well was drilled with spud mud down to 1018 m and with\r\nKCl / polymer / Anco 208 (glycol additive) mud from 1018 m to TD. It was one of\r\nthe first to be drilled with a glycol mud system to inhibit reactve shales. \u003c/p\u003e\r\n\r\n\u003cp\u003eDown to the Base Cretaceous at 3471.5 m\r\n(3343 m TVD RKB), the well penetrated mainly claystones. The shallowest\r\nprospect, the Cretaceous sequence, was penetrated in a distal position, and\r\nhence was most likely shaled out. The Jurassic comprised the Late Jurassic\r\nHekkingen and Fuglen Formations and the Early to Middle Jurassic Stø Formation.\r\nThe secondary Hekkingen prospect was penetrated about 720 m deeper than\r\nprognosed and was only 9 m thick. Pressure test indicated a tight formation.\r\nThe large difference between the prognosed and actual depth was mainly due to a\r\nmuch thicker Early Cretaceous sequence than prognosed. The main prospect, the\r\nStø Formation, was penetrated 450 m deeper than prognosed. The Sandstone with\r\nporosity in order of 5-8%, was water bearing. The relatively tight sandsto","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"832","properties":{"OBJECTID":832,"wlbNpdidWellbore":2038,"wlbName":"31/2-18 A","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThe purpose of well 31/2-18 was to appraise the structure\r\nand oil bearing potential of a fault block in the northern part of the Troll\r\nWest Gas province (TWGP). The objectives for drilling well 31/2-18 were to\r\nevaluate the structure for future development of oil producing wells in the\r\nTWGP-North area, and to determine the degree of development required to\r\nefficiently develop the oil reservoir in the TWGP-North area. Well 31/2-18A was\r\ndrilled as a pre-planned sidetrack to Well 31/2-18 in order to evaluate the\r\nhydrocarbon potential of the Krossfjord Formation. The primary objective of the\r\nsidetrack was to evaluate a seismic anomaly, or "flat spot" which had\r\nbeen identified in the Krossfjord Formation. The location of the anomaly was situated\r\n240 m to the northeast in an up thrown block, adjacent to the original well.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eAppraisal well 31/2-18 was spudded with\r\nthe semi-submersible installation "Treasure Saga" on 15 September\r\n1992, and drilled to a total depth of 1711 m in the Middle Jurassic Fensfjord\r\nFormation. The well was drilled with seawater and hi-vis pills down to 940 m\r\nand with KCl/Polymer mud from 940 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003ePalaeocene sand was encountered below\r\nbase Våle Formation, from 1519.9 m to 1528.8 m. This sand is in direct contact\r\nwith the underlying Late Jurassic Sognefjord Formation, which was encountered\r\nover the interval 1528.8 m - 1642.7 m. Gas was proven all through these sands\r\nfrom top of the Palaeocene sand down to 1571.2 m in the Sognefjord Formation. A\r\nthin oil leg was identified, with an oil-water contact at 1582.0 m. Sixteen\r\ngood RFT pressure measurements, including segregated samples at 1575 m and 1582\r\nm, were taken in one run over the interval 1522 m & 1689.5 m. The interval\r\nfrom 1498 m to 1678.5 m (Lower Rogaland Group including the Palaeocene sand,\r\nSognefjord Formation, and Heather Formation) was cored in twelve cores with 86\r\n100 % recovery. \u003c/p\u003e\r\n\r\n\u003cp\u003eAfter running wire line lo","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"833","properties":{"OBJECTID":833,"wlbNpdidWellbore":2043,"wlbName":"15/9-19 S","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 15/9-19 S was the first well\r\nto be drilled into the Theta Vest Structure north of the Sleipner East Field.\r\nIt was designed to test gas from the Heimdal reservoir, and to provide\r\ngeological and reservoir data enabling optimal reservoir management. The\r\nsecondary target was the Hugin/Skagerrak Sands, which were to be fully\r\nevaluated if hydrocarbon bearing.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 15/9- 19 S was spudded with the\r\nsemi-submersible installation Treasure Prospect on 18 November 1992, from Slot\r\n3 of the Loke Discovery template. The well was deviated, penetrating the top of\r\nthe Theta Vest structure approximately 2290 m west northwest of the Loke\r\nTemplate, and reached the target Top Heimdal Formation at 3622.5 m (2427.0 m TVD\r\nRKB). The 12 1/4" section from 1482 m to 3580 m was drilled with\r\nsignificant problems. Trips out of the hole at 2018 m, 3016 m and 3353 m were\r\nperformed to change the bits, due to low penetration rate. The hole packed of\r\nseveral times when tripping out. Problems with lost returns and stuck BHA\r\nfinally led to plugging back and sidetracking from 1493 m. Attempts to\r\norientate the well became progressively more difficult, especially after\r\npenetrating 3308.5 m in the Balder Formation. The Lista Formation was encountered\r\nat 3483 m, and final TD was set at 3580 m, at the edge of the Heimdal Formation\r\ntarget. The well was drilled with bentonite mud down to 531 m, and with\r\nKCL/POLYMER (Phpa/pac) mud from 531 m to TD in the first hole. After\r\nsidetracking oil based mud (Petrofree) was used.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well penetrated 150 m TVD of Tertiary\r\nsands between 1313 m and top Balder Formation at 3302 m. \u003c/p\u003e\r\n\r\n\u003cp\u003eIt was temporarily suspended on 31\r\nJanuary 1993 after setting 9 5/8" casing at 3569.0 m (2394.0 m TVD RKB),\r\nimmediately above the Heimdal sands. No cores were cut and no fluid samples\r\ntaken in this well bore. It is classified as a dry well.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was perfo","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"834","properties":{"OBJECTID":834,"wlbNpdidWellbore":2044,"wlbName":"2/5-10","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eExploration well\r\n2/5-10 is located in the Central Graben on the Steinbit Terrace. The well was\r\ndrilled with Late Jurassic sandstone of Oxfordian age, in a combination trap\r\nwith structural and dip closing elements, as the primary target. Secondary\r\ntargets were the Middle Jurassic Bryne Formation in the same combination\r\ntrapping configuration, while the Late Cretaceous Chalk and the Lower\r\nCretaceous Cromer Knoll Group were stratigraphic trap targets. After reaching\r\nTD evaluation of the cores and electric logs concluded that a fault had been\r\nintercepted within the main Jurassic target, justifying a sidetrack in search\r\nof a better pay zone. Well 2/5-10 was therefore plugged back in and well 2/5-10\r\nA sidetracked. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 2/5-10 was\r\nspudded with the semi-submersible installation "Polar Pioneer" on 23\r\nMay 1993 and drilled to TD at 4701 m in rocks of the Triassic Smith Bank\r\nFormation. The well was drilled with sea water and hi-vis sweeps down to 865 m,\r\nwith KCl/Polymer mud from 865 m to 4235 m, and with HPHT/Polymer mud from 4235\r\nm to TD. Shallow gas was encountered after drilling the 8 1/2" pilot hole,\r\nprior to opening up the hole to 26" and running 20" casing. In order\r\nto ensure a good 20" casing cement job without compromising rig safety it\r\nwas decided to plug back the gas bearing zone and set 20" casing at 509m,\r\n291m shallower than originally planned 800m. To avoid gas migration the cement\r\nslurries for the 20" and 13 3/8" were redesigned with gas tight\r\ncement (microblock added). \u003c/p\u003e\r\n\r\n\u003cp\u003eTop reservoir was\r\nencountered at 4582 m, 174 m deeper than prognosis due to complex geology and\r\nhigher than expected shale interval velocities in the Late Jurassic. The main\r\npart of the Late Jurassic sandstone target was removed by faulting, and\r\nTriassic strata were encountered 5 m below top reservoir through a fault plane.\r\nThe Late Jurassic sandstone was highly affected by the faulting,","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"835","properties":{"OBJECTID":835,"wlbNpdidWellbore":2049,"wlbName":"7128/4-1","wlbHistory":"\r\n\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 7128/4-1 is located in the Finmark\r\nØst area. The main objective for the well was to test the potential for\r\nhydrocarbons in Visean sandstone on the "Omd Vest" structure. The\r\nsecondary objective was to test the hydrocarbon potential, reservoir and trap\r\npossibilities of the Asselian - Sakmarian carbonates and the upper Permian\r\nsuccession.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eExploration well 7128/4-1 was spudded\r\nwith the semi-submersible installation "Ross Rig" on 17 December 1993\r\nand drilled to TD at 2530 m in pre-Devonian basement rocks, 27 m below base of\r\nthe Early Carboniferous Soldogg Formation. The well was drilled with seawater\r\nand bentonite / CMC EHV spud mud down to 770 m and with GYP/PAC mud from 770 m\r\nto TD. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well penetrated Quaternary, Tertiary,\r\nTriassic, Permian, and Carboniferous sediments. The Cretaceous and Jurassic\r\nsequences were not present. Gas chromatography readings during drilling and log\r\nevaluation indicated gas saturation in the primary target. The sandstone was\r\nvery tight and therefore not production tested. However, the Late Permian\r\nspiculite was partly very porous and permeable with a gas cap over moveable\r\noil. A GOC was indicated at 1575 m. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eA total of five conventional cores were\r\ncut in the well 1574 m t 1577 m (Late Permian Røye Formation), 1814 m to 1837 m\r\n(Isbjørn and Ørn Formations of\u00A0 Early Permian age), 1837 m to 1865 m (Early\r\nPermian Ørn Formation), 2362 m to 2389.47 m (Early Carboniferous Soldogg\r\nFormation), and 2526 m to 2530 m (Pre-Devonian basement). \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eFMT wire line samples were obtained from three\r\nlevels: 1572.7 m, 1576 m, and 1588.8 m. In the FMT samples taken at 1572.7 m,\r\nthe 10-","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"836","properties":{"OBJECTID":836,"wlbNpdidWellbore":2050,"wlbName":"2/10-2","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 2/10-2 is\r\nlocated in the western area of block 2/10 in PL163, in an inverted half graben\r\nstructure at the Grensen Spur. The block, being the southernmost in the\r\nNorwegian North Sea sector, borders both the UK and Danish sector lines, and\r\nheld only one previously drilled exploration well at the time of drilling\u003c/p\u003e\r\n\r\n\u003cp\u003eThe main objective\r\nof the well was to test the hydrocarbon potential of Late Jurassic sandstones,\r\nprospect-A, a combined structural and stratigraphic trap located in the hanging\r\nwall of a half graben structure. The well should also test the prospectivity of\r\nthe Shetland Group, which held oil in the Tor Formation in well 2/7-2; the\r\nreservoir potential of the Cromer Knoll Group in stratigraphic closures formed\r\nby pinch outs against Base Cretaceous Unconformity; and possible hydrocarbon\r\npotential of the pre-Triassic/Rotliegendes Group.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eExploration well\r\n2/10-2 was spudded with the semi-submersible installation "Treasure\r\nSaga" on 16 February and drilled to TD at 4164 m in rocks of undefined age.\r\nThe well was drilled with spud mud down to 1169 m, with KCl mud from 1169 m to\r\n3681 m, and with "HI TEMP" polymer mud from 3681 m to TD. The Tor and\r\nHod limestones slowed down the penetration rate in the 12 1/4" section.\r\nDrill string vibrations and torque fluctuations were created which ruined\r\nseveral bits and resulted in one drill string failure.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe 8 3/8"\r\nsection was surprisingly easy to drill. It was easy to achieve penetration\r\nrates of 15 m/hr, but due to geological and pressure control, the penetration\r\nrate had to be controlled through most of the section. The pore pressure\r\nincreased very rapidly at top of the Mandal Formation, and the mud weight had\r\nto be adjusted accordingly. The mud weight was increased from 1.70 SG to 1.95\r\nSG over an interval of approximately 30 m. Maximum estimated bottom hole static\r\ntemperature was approximately 150°C based on Horner p","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"837","properties":{"OBJECTID":837,"wlbNpdidWellbore":2057,"wlbName":"34/8-7 R","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 34/8-7 is\r\nlocated on the western flank of the Tampen Spur and is situated approximately\r\n7.4 kilometres due east of well 34/8-4S, in the Visund prospect. This was the\r\nthird exploration well to be drilled in the licence area. The primary objective\r\nof well 34/8-7 was to test the Jurassic Brent Group and Statfjord Formation in\r\nthe hanging wall of the Visund Fault. The secondary objectives were to\r\nestablish a good seismic to well correlation and to fulfil licence obligations.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eExploration well\r\n34/8-7 was spudded with the semi-submersible rig "Polar Pioneer" on\r\n21 March 1992 and drilled to TD at 5460 m in the Triassic Hegre Group. The well\r\nwas drilled with spud mud down to 1444 m and with KCl/PHPA/Polymer mud from 1444\r\nm to 3288 m. From 3288 m the mud system was gradually changed to a HTHP (high\r\ntemperature stable polymers) mud. Still, towards TD of the well it was evident\r\nthat some of the chemical/polymers was decomposing and forming carbonates.\u003c/p\u003e\r\n\r\n\u003cp\u003eConglomeratic\r\ndensity flow deposits (Intra Draupne Formation sandstone) were found in the\r\nupper part of the Draupne Formation. From a gross thickness of 134.5m, 5.75m of\r\nnet sand were identified of which 5.25m were regarded as net pay. An average\r\nporosity value 9.4% and average Sw of 50.1% were computed for the pay section.\r\nA core cut in the Intra Draupne sandstone gave 5.2 % core porosity on average.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe primary\r\nobjective Brent Group was encountered at 4632.5 m. The entire Brent Group was\r\ninterpreted as being gas bearing. From a gross thickness of 134.5m, 36.5m of\r\nnet sand were recognised with 36.5m of net pay. An average porosity of 9.8% and\r\naverage Sw of 30.4% were determined. A core cut in the Brent Group, gave an\r\naverage porosity of 9.9 %. The sandy member of Cook Formation was found to be\r\ngas bearing, but poor reservoir properties reduced the net pay to only 2.0 m\r\nwith an average porosity of 8.3 % and average Sw of 36.1 %.\u003c/p\u003e\r\n\r\n\u003cp\u003eNo","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"838","properties":{"OBJECTID":838,"wlbNpdidWellbore":2059,"wlbName":"31/5-5","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was drilled as part of the\r\nappraisal programme initiated for the southern part of the Troll West Gas\r\nprovince (TWGP-S). The objectives of the well were to provide geological,\r\ngeophysical and petrophysical data for evaluation of the potential for a group\r\nof oil producers in TWGP-S; and to provide data on the Fensfjord and Krossfjord\r\nFormations to improve aquifer modelling. The well was further planned for later\r\nre-entry, either for sidetracking and completion as a horizontal producer, or\r\nfor vertical recompletion for Sognefjord Formation reservoir monitoring.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 31/5-5 was spudded with the\r\nsemi-submersible installation West Delta on 30 December 1992 and drilled to a\r\ntotal depth at 1930 m in the Middle Jurassic Krossfjord Formation. The well was\r\ndrilled with spud mud to 940 m and with KCl/brine from 940 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe Sognefjord Formation was encountered\r\nfrom 1572 m to 1725 m, and was hydrocarbon bearing. Strong oil shows were\r\nrecorded from 1573 m to1587.5 m, weaker oil shows were recorded below this\r\ndepth down to 1650 m. The gas-oil contact was identified at 1573.5, and the\r\noil-water contact was identified at 1585.5 m. From FMT pressure tests a gas\r\ngradient of 0.152 g/cc, an oil gradient of 0.825 g/cc, and a water gradient of\r\n1.02 g/cc was defined. Twelve conventional cores were cut. The first ten were\r\nfrom 1555 m in the top of the Sognefjord Formation to1726 m, one meter into the\r\nFensfjord Formation. Cores 11 and 12 were cut from 1835 m in the Fensfjord\r\nFormation to 1888 m in the Krossfjord Formation. FMT fluid samples were taken\r\nat 1583 m (two samples, both contained oil and gas), 1576.5 m (oil and gas),\r\nand at 1571 m (gas). \u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was temporarily plugged at 1450\r\nm and 450 m using two 9 5/8" Baker type N1 bridge plugs and suspended as\r\nan oil and gas appraisal well on 11 February 1993.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was performed\u003c/p\u003e\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"839","properties":{"OBJECTID":839,"wlbNpdidWellbore":2068,"wlbName":"34/7-21 A","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eExploration well 34/7-21 A is a sidetrack\r\nto well 34/7-21 which found oil in three different sands in the Late Jurassic -\r\nEarly Cretaceous succession. No OWC was found. The primary purpose of the\r\nsidetrack was to test the extension of these discoveries and to prove possible\r\nOWC(s). A secondary objective was to test the presence of sandstones, and\r\npossible hydrocarbons, within the Late Cretaceous in which a thin sandstone\r\ninterval was proved oil-bearing in well 34/7-21.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 34/7-21A was kicked off from 1798 m\r\nin the vertical well on 16 December 1992. The well was deviated and penetrated\r\nthe top reservoir 585 m west of the vertical well. It was drilled with the semi-submersible\r\ninstallation Treasure Saga to TD at 3360 m (2874 m TVD), 37 metres TVD into the\r\nBrent Group. Initial problems with steering the drill string resulted in a kick-off\r\nin the wrong direction. The well was turned around and lined up to the correct\r\nazimuth. The drill string got mechanically stuck three times in the interval\r\n2465 m to 2571 m, but came free within short time. The string also got stuck at\r\n2998 m when running in the hole after waiting on weather. The hole apparently\r\ndeteriorated with time. The TD caliper log showed severe washouts of the hole,\r\nup to a maximum of 22". Waiting on weather for about 17 days was seen to\r\nbe a major cause of the severe washouts. The washouts and hence increased\r\namounts of cuttings, possibly explain the problems with the hole packing off\r\nand the string becoming stuck. Due to the hole angle and the bad hole condition\r\nlogging operations were troublesome and time consuming, with many of the logs\r\nbeing run on drill pipe. The sidetrack was drilled with a KCl mud all through.\r\nThe KCl levels were high and in addition glycol was introduced to inhibit the\r\nformation, but without the wanted effect as proved by the severe washout. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe Base Cretaceous Unconformity was penetrated\r\nat 2870 m. A 3 m thick san","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"840","properties":{"OBJECTID":840,"wlbNpdidWellbore":2072,"wlbName":"16/1-4","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\u003cp\u003eThe objectives of\r\nexploration well 16/1-4 were to test Paleocene sandstones (Heimdal Formation)\r\nin prospect C and Eocene sandstones (Grid Formation) in prospect D. Prospect C\r\nwas the main target. Oil was the prognosed hydrocarbon type. It was expected to\r\npenetrate a pre-Cretaceous sedimentary sequence, although the well location was\r\nnot optimal for a test of the pre-Cretaceous. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 16/1-4\r\nwas spudded with the semi-submersible installation "Deepsea Bergen"\r\non 17 March 1993 and drilled to TD at 2010 m, 146 m into basement rocks. The\r\nwell was drilled with spud mud / hi-vis pills down to 324 m and with "ANCO\r\n2000" mud from 324 m to TD. Well 16/1-4 penetrated sedimentary rocks of\r\nQuaternary, Tertiary, and Cretaceous ages, in addition to basement rocks of\r\nunknown age. No pre-Cretaceous sediments were present in the well. In the\r\nTertiary, reservoir quality sandstones were present in the Miocene and the\r\nOligocene (Utsira and Skade Formations) and in the Eocene Grid Formation. The\r\nGrid sandstones were thinner than expected. No sandstones were developed in the\r\nPaleocene (Rogaland Group) at the well location. The carbonates in the Shetland\r\nGroup were dated to be of Early Paleocene, Danian age. The lower Cretaceous\r\nsediments in well 16/1-4 are 4 m thick (1860 m -1864 m) and consist of clay\r\nstone/marls and immature sandstones with grains of igneous rocks similar to the\r\nbasement rocks below. These sediments are dated to be of Early Aptian age and\r\nhave been identified as the Sola Formation of the Cromer Knoll Group. The\r\nbasement rocks consist mainly of brecciated igneous rocks. No hydrocarbon shows were observed in the Grid Formation sandstones.\r\nGas-condensate was encountered in the upper part of the drilled basement section.\r\nCores were cut in the Eocene Grid Formation and in the Hordaland Group shales\r\nbetween upper and lower Grid Formation (cores 1-3), in the Paleocene Balder-\r\nand Sele Formations (","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"841","properties":{"OBJECTID":841,"wlbNpdidWellbore":2076,"wlbName":"30/9-14","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 30/9-14 is\r\nlocated in the western part of block 30/9, on the Southern Oseberg complex. The\r\nprimary objectives of the well were to appraise oil within the G-North prospect\r\nand verify the potential resources of the G-North and G-West prospect, leaving\r\na minimum of untested resources up dip of the well on the G-North prospect; to\r\ndefine fluid contacts, primarily the OWC in the Tarbert Formation; and to\r\nverify the structural mapping, depth conversion and the geological model for the\r\nG-North area. Secondary objectives were to verify the lateral extent of the\r\nlower Heather sand, to test a possible hydrocarbon potential within the Ness\r\nand ORE (Oseberg/Rannoch/Etive) Formations, and to obtain a good well tie of\r\nthe base Brent reflector and the intra Dunlin reflector.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eAppraisal well\r\n30/9-14 was spudded with the semi-submersible installation \"Polar\r\nPioneer\" on 16 March 1993 and drilled to total depth at 3680 m in the\r\nEarly Jurassic Drake Formation. The well was drilled water based with sea water\r\nand hi-vis pills in the 36\", 24\", and 17 1/2\" sections, down to\r\n1040 m, and with a KCl / PHPA / Polymer mud from 104 m to TD. Sedimentological\r\nand lithological development was similar to 30/9-13 S, but approximately 250 m\r\nof Early Oligocene sand encountered in well 30/9-13 S was not present in well\r\n30/9-14 where the same interval is dominated by clay stone. The Viking Group\r\ncame in at 2967 m and the Top Tarbert Formation came in at 3059.5 m, 84 m\r\ndeeper than prognosis due to too low velocities in the Tertiary section.\r\nSixty-six m of Intra Heather Sandstone was verified from 2993.5 m to 3059.5 m.\r\nPoor to moderate shows were observed in the Draupne and Heather Formations from\r\n2968.5 m to 3059.5 m. Moderate to good shows were seen from 3059.6 m to 3130 m\r\nin the Tarbert Formation. Good shows (residual oil) were also observed in the\r\nORE Formation from 3503 - 3514 m. The Lower Heather and upper Tarbert\r\nFormations were proven to","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"842","properties":{"OBJECTID":842,"wlbNpdidWellbore":2080,"wlbName":"34/8-8 R","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 34/8-8 R is a re-entry of appraisal\r\nwell 34/8-8 on the N-1 segment of the 34/8-1 Visund discovery on Tampen Spur in\r\nthe Northern North Sea.\u003c/span\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003cspan lang=EN-GB\u003eThe\r\nprimary objective of well 34/8-8R was to determine the pressure regime and\r\npressure gradient in the hydrocarbon bearing sands in Tarbert, Ness and Etive\r\nformations. The secondary objective was to determine the fluid\r\nsystem/composition and the possible presence of a gas oil contact in the\r\nTarbert/Ness formations. The third objective was to investigate the mobility of\r\noil and water down to the interpreted free water level (FWL)\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 34/8-8 was re-entered on 16 February\r\n1993 with the semi-submersible installation Polar Pioneer.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was drill stem tested. No significant\r\nproblems occurred in the operations. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo cores were cut and no wire line fluid\r\nsamples were taken.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was permanently abandoned on 9\r\nMarch 1993 as an oil appraisal.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eTesting\u003c/span\u003e\u003c/b\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eTwo drill stem tests were performed. In\r\nboth tests production logging (PLT) was performed during the main flow.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eDST 1 tested the interval 2960.2 to\r\n2973.2 m in the Ness/Etive formations. The test sequence consisted of an\r\ninitial and a cleanup flow/build-up period with down hole shut-in. The main\r\nflow with PLT was interrupted by poor weather conditions and the well was\r\nimmediately killed. Only a limited amount of the surface sampling program was\r\ntherefore accomplished. No down hole sam","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"843","properties":{"OBJECTID":843,"wlbNpdidWellbore":2084,"wlbName":"15/6-7","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 15/6-7 was the first well in licence\r\n166. The primary objective of the well was to test the hydrocarbon potential of\r\nthe Middle Jurassic, Hugin Formation of Callovian age within a seismically\r\ndefined structural trap. There were no secondary objectives for the well,\r\nhowever, other potential reservoir horizons, albeit outside closure, were\r\nanticipated within the early Tertiary succession. The well programme was\r\ndesigned to maximize the evaluation of these sections as\u003c/p\u003e\r\n\r\n\u003cp\u003erequired. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eExploration well 15/6-7 was spudded on 24\r\nApril 1993 with the semi-submersible installation "Vildkat Explorer"\r\nand drilled to TD at 3540 m in the Triassic Smith Bank Formation. The well was\r\ndrilled with gel and seawater down to 505 m, with PHPA/KCl mud from 505 m to\r\n1173 m, with PHPA/KCl/Glycol mud from 1173 m to 2788 m, and with PHPA/KCl mud\r\nfrom 2788 m to TD. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe Quaternary and Tertiary sequence\r\nrepresented by the Nordland, Hordaland and Rogaland Group is dominated by\r\nmudstone lithologies with occasional thick sandstone developments in the\r\nUtsira, Grid, and Heimdal Formations. Background gas values ranged from less\r\nthan 0.1% to 0.5% with rare isolated gas peaks. The Late Cretaceous succession\r\nin the well, 493 m thick, is dominated by carbonate lithologies of the Shetland\r\nGroup; below 3150 m these become increasingly and atypically sandy. A number of\r\ngas peaks were recorded over the interval 3025 m to 3157 m with a maximum gas\r\npeak of 5.42% recorded at 3154 m. The Early Cretaceous, 14.5 m thick,\r\nrepresented by the Cromer Knoll Group is substantially thinner than anticipated\r\nand consists of arenaceous limestones interbedded with thin calcareous\r\nsandstones. The Upper Jurassic Draupne Formation was penetrated at 3233 m, 36 m\r\nlow to prognosis. Intra Draupne Formation Sandstone was encountered at 3292 m.\r\nA formation fluid influx of 3.9 m3 equivalent to a calculated pore pressure of\r\n1.5 sg (RFT) occurred at 33","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"844","properties":{"OBJECTID":844,"wlbNpdidWellbore":2095,"wlbName":"25/2-15 R","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well is located in the southern part\r\nof block 25/2, and was designed to recognize the petroleum potential of the\r\nso-called Jurassic Prospect 1. The main objective of the well was to explore\r\nthe Middle Jurassic Brent sandstones. An optional objective was Early Jurassic\r\nStatfjord sandstones, depending on the petroleum results at the Brent level. \u003c/p\u003e\r\n\r\n\u003cp\u003eWell 25/2-15 R is a re-entry of well\r\n25/2-15, which was drilled with the semi-submersible installation West Alpha.\r\nDue to a fire on the West Alpha installation the well was temporarily abandoned\r\non 13 January 1993, with the drill string in the hole. The purpose with the\r\nre-entry was to retrieve the West Alpha BOP, fish out the lost drill string,\r\nperform logging, and set 9 5/8" casing. After that normal exploration\r\ndrilling would be resumed to fulfil the original geological objectives.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 25/2-15 was re-entered\r\n(25/2-15 R) with the semi-submersible installation West Vanguard on 6 February\r\n1993. West Vanguard was chosen due to availability and compatibility with the\r\nWest Alpha BOP system. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe lost drill string was successfully\r\nfished and retrieved and the hole was logged. Due to poor hole conditions after\r\nthree weeks of open hole the logging program was not successfully accomplished.\r\nThe 9 5/8" casing was ran and cemented with shoe at 3498 m. The well was\r\ntemporary plugged, the drill string laid down, the West Alpha BOP was retrieved\r\nand secured on the BOP trolley. \u003c/p\u003e\r\n\r\n\u003cp\u003eAll geological results from the well are\r\ngiven in the 25/2-15 R2 history.\u003c/p\u003e\r\n\r\n\u003cp\u003eOn 1 March 1993 the well was suspended,\r\nand the rig was moved to Dusavika for BOP change out. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was performed in the\r\nwell.\u003c/p\u003e\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"845","properties":{"OBJECTID":845,"wlbNpdidWellbore":2105,"wlbName":"15/9-19 SR","wlbHistory":"\r\n\r\n\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe re-entry 15/9-19 SR is a continuation\r\nof wildcat well 15/9-19 S, which was temporarily suspended at 3569.0 m (2394.0\r\nm TVD RKB), immediately above the Heimdal sands. The target of the well was the\r\nTheta Vest Structure north of the Sleipner East Field. The primary objective\r\nwas to test gas from the Heimdal reservoir, and to provide geological and\r\nreservoir data enabling optimal reservoir management. The secondary target was\r\nthe Hugin/Skagerrak Sands, which were to be fully evaluated if hydrocarbon\r\nbearing. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 15/9- 19 S was re-entered (15/9-19\r\nSR) with the semi-submersible installation Treasure Prospect on 17 February\r\n1993, from Slot 3 of the Loke Discovery template. The well was drilled to TD at\r\n4641 m (3132.3 m TVD RKB) in the Triassic Skagerrak Formation. No significant\r\ntechnical problems were encountered in this well bore. The well bore was\r\ndrilled with oil-based mud (Petrofree).\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe Heimdal sandstone was penetrated at\r\n3623 m (2427 m TVD RKB), 50 m low to prognosis. This Formation was the main\r\ntarget in the well. No hydrocarbons were encountered. The Hugin Formation was\r\npenetrated at 4317 m (2886 m TVD RKB), 2 m low to prognosis. The entire Hugin\r\nFormation was oil filled (18 m TVD). The core from this formation was filled\r\nwith H2S (650 ppm). Sandstones of the Skagerrak Formation were water wet. No\r\nshows were recorded due to invasion of petrofree mud. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eOne core was cut from 3643 m to 3648 m in\r\nthe Heimdal Formation, and two cores were cut from 4328 m to 4383 m in the\r\nHugin and Skagerrak Formations.No fluid samples were taken.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was suspended on 29 March 1993\r\nas an oil discovery.\u003c/s","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"846","properties":{"OBJECTID":846,"wlbNpdidWellbore":2106,"wlbName":"31/2-17 BR","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 31/2-17 BR is a re-entry of well\r\n31/2-17 B. The objective of the re-entry was plugging and permanent\r\nabandonment.\u00A0 \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 31/2-17 B was re-entered (31/2-17\r\nBR) with the semi-submersible installation West Delta on 14 February 1993.\r\nOperations took 11 days, which included 6 days down-time due to wait on weather\r\nand problems with connecting Guide base and BOP to old well head. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was plugged and permanently\r\nabandoned on 24 February 1993 as a gas and oil appraisal.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was performed\u003c/p\u003e\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"847","properties":{"OBJECTID":847,"wlbNpdidWellbore":2113,"wlbName":"7/7-3","wlbHistory":"\u003cp\u003eWell 7/7-3 is located ca 5 km east of the\r\n UK border on the Jæren High in the North Sea. It was drilled to appraise the\r\nLate Jurassic discovery in well 7/7-2 and was designed to test seismic\r\ninterpretations, reservoir thickness and properties, pressure regime, and\r\nvolume of recoverable oil. The well was planned as a future injector, but since\r\nthe reservoir only indicated traces of hydrocarbons it was permanently plugged.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 7/7-3 was spudded with the semi-submersible\r\ninstallation Deepsea Bergen on 20 April 1993 and drilled to TD at 3584 m in the\r\nLate Permian Zechstein Group. The well took 17 days more than planned to drill,\r\nmainly due to a 8,5 days downtime related to BOP repair and loss of circulation\r\nat end of 12 1/4" section. The well was drilled with seawater and hi-vis\r\npills down to 918 m, and with ANCO 2000 mud from 918 m to 2677 m. From 2677 m\r\nto 3354 m the mud was gradually displaced to an ANCOTHERM/Bentonite system. The\r\nANCOTHERM/Bentonite system was used from 3354 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe 7/7-3 well penetrated the Ula\r\nFormation at 3490.5 m. The siltstone and the uppermost 2 metres of the\r\nsandstone showed only weak shows and the following logging and evaluation\r\nconfirmed that the sandstone did not contain any moveable hydrocarbons. \u003c/p\u003e\r\n\r\n\u003cp\u003eThree cores were cut from 3486 m to 3516\r\nm, from base Farsund Formation, through the Ula Formation and into the Triassic\r\nGroup. Two segregated FMT fluid samples were taken at the same depth, 3497.3 m.\r\nAll fluid chambers proved to contain mud filtrate and water and did not contain\r\nany hydrocarbons.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 4\r\nJuly 1993 as dry with shows.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was performed\u003c/p\u003e\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"848","properties":{"OBJECTID":848,"wlbNpdidWellbore":2114,"wlbName":"33/9-17","wlbHistory":"\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 33/9-17 is located immediately north\r\nof the Statfjord field, northwest of the Statfjord Nord field with the\r\nMurchison field to the west.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe primary objective of the well was to\r\nevaluate the hydrocarbon potential of intra-Draupne sandstone informally named\r\nthe Munin sandstone unit. It was designed to find commercial hydrocarbons in a\r\nstructural/stratigraphic play above 3080 meters sub-sea, the interpreted\r\noil/water contact. The secondary objective was to evaluate the Middle Jurassic\r\nsandstones of the Brent Group.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 33/9-17 was spudded on 2 April 1994\r\nwith the semi-submersible rig Treasure Saga and reached a total driller's depth\r\nof 3233 m RKB in the Middle Jurassic Brent Group. The well was drilled with\r\nseawater and swept with high viscosity mud down to the 12 1/4" section,\r\nwhile KCl/polymer/Glycol mud was used when drilling the 12 1/4" section\r\nand to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe Munin sandstone unit (3050 - 3131m) was\r\nmostly water bearing with localized hydrocarbon shows. Average water saturation\r\nwithin the reservoir is 89.2%. The unit consisted of 47.3 meters of net\r\nreservoir out of a gross interval of 81 meters (N/G = 58.4%). The net reservoir\r\nwas of excellent quality. Average Munin porosity was 22.6% and permeability was\r\ngenerally over l Darcy. The Brent Group (3187 -3233m) has 22.9 meters of good\r\nquality reservoir rock from a gross sandstone thickness of 37 meters, but is\r\nwater bearing. Average porosity for the reservoir rock is 19.7%.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNone of the analysed potential source\r\nrocks of this well are within the oil window and only limited early generation\r\nof hydrocarbons has taken place. The Viking Group cla","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"849","properties":{"OBJECTID":849,"wlbNpdidWellbore":2116,"wlbName":"25/2-15 R2","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well is located in the southern part\r\nof block 25/2, and was designed to recognize the petroleum potential of the\r\nso-called Jurassic Prospect 1. The main objective of the well was to explore\r\nthe Middle Jurassic Vestland sandstones. An optional objective was Early Jurassic\r\nStatfjord sandstones, depending on the petroleum results at the Brent level. \u003c/p\u003e\r\n\r\n\u003cp\u003eWell 25/2-15 R is a re-entry of well\r\n25/2-15, which was drilled with the semi-submersible installation West Alpha.\r\nDue to a fire on the West Alpha installation the well was temporarily abandoned\r\non 13 January 1993, with the drill string in the hole. The 25/2-15 R re-entry\r\nretrieved the West Alpha BOP, fished out the lost drill string, performed\r\nlogging, and set 9 5/8" casing. After that, the hole was again suspended\r\nand the installation used, West Vanguard, left to Dusavika for BOP change out.\r\nThe purpose with the 25/2-15 R2 re-entry was to fulfil the original geological\r\nobjectives.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 25/2-15 was re-entered for\r\nthe second time (25/2-15 R2) with the semi-submersible installation West\r\nVanguard on 6 March 1993 and drilled to final TD at 3942 m in the Early\r\nJurassic Dunlin Group. No significant drilling problems were encountered in the\r\nborehole. At 3602 m, during coring, a water kick was detected. At TD a\r\ndiscrepancy of 8 m between driller and log depth was recorded, log depth being\r\nthe deeper.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe Vestland reservoir proved to be water\r\nbearing, with residual hydrocarbon shows. Very good shows were observed in Shetland-limestones\r\nof Late Campanian - Early Maastrichtian age. However, no RFT pressure\r\nmeasurements/fluid samples were achieved. Both the bio- and lithostratigraphy\r\nof the formations in the lowermost part of the well, was initially indistinct.\r\nThe biostratigraphy study however, made it clear that TD of the well was in a\r\nformation belonging to the Dunlin Group, of Late Pliensbachian -Middle Toarcian\r\nage. Two cores were cut in ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"850","properties":{"OBJECTID":850,"wlbNpdidWellbore":2124,"wlbName":"2/7-29","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 2/7-29 was the\r\nsecond commitment well on licence PL 145. The primary objective was to\r\nestablish the presence, quality and fluid content of Jurassic sandstones in\r\nProspects JU2 and JU7 via cores and wire line logs and to evaluate their\r\nproductivity and fluid properties if hydrocarbon bearing. The pre-Cretaceous\r\nwas to be accurately dated via biostratigraphy. The secondary objective was to\r\nverify the presence, quality and fluid content of Permian sandstones in\r\nProspect P2, and if possible to test the margin of the Jurassic JU2-B Prospect\r\nlocated stratigraphically between JU2 and JU7.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eExploration well\r\n2/7-29 was spudded with the jack-up installation "Maersk Guardian" on\r\n18 September 1993 and drilled to TD at 4900 m in mudstones of the Permian\r\nRotliegend Group. A 9 7/8"pilot hole was drilled to 310 m before opening\r\nto 36" to evaluate possible shallow gas. No shallow gas was observed and\r\nthe 30" casing was set at 302 m. A further 9 7/8" pilot hole was\r\ndrilled to 1155 m before opening to 26" and the 20" casing set at\r\n1146 m. The well was drilled with seawater and hi-vis sweeps down to 310 m,\r\nwith bentonite mud from 310 m to 1153 m, and with synthetic oil (ester) based\r\n"AQUAMUL B II EBM" mud from 1153 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eHydrocarbons were\r\nencountered in 129m of gross (49m net) sandstone in the JU2 prospect (Eldfisk Fm.), the\r\nshallower of the Jurassic prospects. Log evaluation established an Oil-Down-To\r\nat 4530 m TVDSS. Mean porosities of 12% and permeability in the range 0.01 to\r\n80 mD were measured from core and log data over the pay zone. The mean reserves\r\nfor the discovery are estimated at 9.3mmbbl (1.48mmcum). Two sand intervals of\r\n12.5 and 19m gross thickness were encountered in the JU7 target. The upper\r\ninterval contained hydrocarbons. A gross sandstone thickness of 46m was\r\nencountered in the Early Permian, although no hydrocarbons were present. \u003c/p\u003e\r\n\r\n\u003cp\u003eA ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"851","properties":{"OBJECTID":851,"wlbNpdidWellbore":2128,"wlbName":"6506/12-9 S","wlbHistory":"\u003cb\u003e\r\nGeneral\r\n\u003c/b\u003e\r\n\u003cp\u003e\r\nThe main objective of well 6506/12-9 S was to appraise the oil and gas potential within the Ile and Tilje Formations. \r\n\u003c/p\u003e\r\n\u003cb\u003e\r\nOperations and results\r\n\u003c/b\u003e\r\n\u003cp\u003e\r\nAppraisal well 6506/12-9 S was spudded 5 April 1993 with the semi-submersible installation \"Ross Isle\" and drilled to a total depth of 4910 m driller's depth (4903 m TVD), 4915.2 m loggers depth (4908.2 m TVD), into rocks of Early Jurassic age. Oil and gas was encountered in the Early to Middle Jurassic Båt and Fangst Groups. The well was drilled with seawater and hi-vis pills down to 802 m, Gyp/PAC mud from 802 m to 2242 m, Anco 2000 with glycols (Anco 208) from 2242 to 4378 m, and with Ancotherm mud from 4378 to TD. A total of 13 cores were cut in this well. Two were cut in the Paleocene Tang formation but these only 0,35m was recoverd(1%)The other 11 cores were cut in the interval 4415 m to 4846.9 m in the Båt and Fangst Groups. Recoveries for these were from 65 to 100%. Three FMT samples were taken in the Tilje Formation.\r\nThe well was abandoned as an oil and gas appraisal on 11 September 1993.\r\n\u003c/p\u003e\r\n\u003cb\u003e\r\nTesting\r\n\u003c/b\u003e\r\n\u003cp\u003e \r\nFive production tests were performed in the Jurassic sandstone section.\r\nDrill stem test no 1 in the Åre formation in the interval 4846.0 to 4876 m produced a near-critical gas condensate. The well production was 444 000 Sm3/day of gas and 840 Sm3/day of condensate through a 44/64\" (17,46 mm) choke size. Density of the gas was 0.832 (air = 1) and condensate density was 0.814 g/cm3.\r\nDrill stem test no 2 tested the Tilje formation in the interval 4805.0 to 4834 m, and it produced a light oil. The well production was 249 000 Sm3/day of gas and 900 Sm3/day of oil through a 56/64\" (22,23 mm) choke size. Density of the gas was 0.832 (air = 1) and condensate density was 0.855 g/cm3.\r\nDrill stem test no 3 tested the Tilje formation in the interval 4742.0 to 4751.0 m, and it produced a light oil. The well production was 138 000 Sm3/day of gas and 567 Sm3/day of oil through a 44/64\" (17.46 mm) choke size. De","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"852","properties":{"OBJECTID":852,"wlbNpdidWellbore":2134,"wlbName":"2/4-18","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003ePL 146 is situated on the Hidra Terrace\r\nalong the eastern margin of the Feda Graben, Southern North Sea. The first\r\nwell, 2/4-14 (1988-89), penetrated an overpressuried reservoir, which was\r\ntested in an updip position by the well 2/4-16 / 2/4-16R. The latter well did\r\nnot confirm the reservoir model. It was then concluded that the zone of main\r\ninterest had to be situated in younger strata, preserved downdip to the east.\r\nWell 2/4-14 was sitting approximately at the pinch-out point of the untested\r\nwedge. Well 2/4-18 was drilled to test this model.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 2/4-18 was spudded with the\r\nsemi-submersible installation Treasure Saga on 26 April 1993. A pilot hole was\r\ndrilled to 622 m in Pliocene sediments (Nordland Group) before it had to be\r\nplugged due to hole stability problems.\u003c/p\u003e\r\n\r\n\u003cp\u003eNo cores were cut and no wire line fluid\r\nsamples taken.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was performed\u003c/p\u003e\r\n\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"853","properties":{"OBJECTID":853,"wlbNpdidWellbore":2136,"wlbName":"7/4-1","wlbHistory":"\u003cb\u003e\r\nGeneral\r\n\u003c/b\u003e\r\n\u003cp\u003e\r\nWell 7/4-1 was drilled on a structure lying on the northeastern flank of the Central Graben. The main objectives for the well were to test commercial reserves of hydrocarbons in the Upper Jurassic of the Alpha prospect and to establish the \"Jæren High\" Model analogy proven by the 7/7-2 discovery well.\r\n\u003c/p\u003e\r\n\u003cb\u003e\r\nOperations and results\r\n\u003c/b\u003e\r\n\u003cp\u003e\r\nExploration well 7/4-1 was spudded with the semi-submersible installation \"Deepsea Bergen\" on 5 July1993 and drilled to TD at 3133 m, 50 m into rocks of the Permian Zechstein Group anhydrite. The well was drilled with seawater and viscous pills down to 926 m and with KCl / polymer / glycol mud from 926 m to TD. \r\n\u003c/p\u003e\r\n\u003cp\u003e\r\nSeventeen m of Late Jurassic sandstones were penetrated. No hydrocarbons were observed. Three cores were cut; one in the interval 2980 m ?2989 m in the Mandal Formation, the second in the interval 3015 m ? 3024 m in the Farsund Formation, and the third in the interval 3069 m - 3077 m in the Gyda Sandstone Member. No fluid samples were taken. The well was permanently abandoned as a dry well on 22 August 1993.\r\n\u003c/p\u003e\r\n\u003cb\u003e\r\nTesting \r\n\u003c/b\u003e\r\n\u003cp\u003e\r\nNo drill stem test was performed.\r\n\u003c/p\u003e\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"854","properties":{"OBJECTID":854,"wlbNpdidWellbore":2141,"wlbName":"30/6-23 R","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 30/6-23 R is a re-entry of well\r\n30/6-23 on the Beta South structure on the Brage Horst south of the Veslefrikk\r\nField in the North Sea. The objective of the re-entry was plugging and\r\npermanent abandonment.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 30/6-23 was re-entered with the semi-submersible\r\ninstallation Polar Pioneer on 16 May 1993. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was plugged and permanently\r\nabandoned on 21 May 1993.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eTesting\u003c/span\u003e\u003c/b\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo drill stem test was performed. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"855","properties":{"OBJECTID":855,"wlbNpdidWellbore":2147,"wlbName":"6407/9-6 R","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eAppraisal well 6407/9-6 was suspended in\r\n1986 as a possible water injection well after a successful oil and water\r\ninjection test in the Late Jurassic Rogn Formation. The objective of the\r\nre-entry 6407/9-6R was plugging and permanent abandonment. A small gas leak\r\nfrom the wellhead was observed when the well was suspended. An inspection\r\nprogramme was initiated to monitor the wellhead and gas leak activity. A\r\nsecondary objective was thus to conclude on the gas leak inspection programme\r\nand take the necessary actions.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eAppraisal well 6407/9-6 R was spudded\r\nwith the semi-submersible installation West Delta (now Deepsea Delta) on 19 May\r\n1993. The gas leak had been observed to diminish during the inspection\r\nprogramme. Since it consisted almost exclusively of methane it was assumed to\r\nhave originated from a minor shallow gas zone and not from the reservoir. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was plugged back and permanently\r\nabandoned on 30 May 1993.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was performed.\u003c/p\u003e\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"856","properties":{"OBJECTID":856,"wlbNpdidWellbore":2153,"wlbName":"2/11-9","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 2/11-9 (South Hod Prospect) is\r\nlocated within production license PL033, which also contains the Hod Field and\r\npart of the Valhall field. The South Hod Prospect extends across the\r\nNorway/Denmark border. Well 2/11-9 was drilled to test the hydrocarbon\r\npotential of pre-Jurassic sandstones contained within a horst block bounded to\r\nthe east by the major Skrubbe Fault. Lower Hod Chalk and postulated possible\r\nLate Jurassic sandstone comprised secondary objectives.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 2/11-9 was spudded with the 3 leg\r\njack-up installation Maersk Gallant on 24 July 1993 and drilled to TD at 4406 m\r\nin Early Carboniferous sediments. The well was drilled in 139 days versus the\r\nplanned 103 days. An incident involving the loss of a 2 Curie Cesium 137 source\r\nfrom the MWD tool at 3816 m in the 12 1/4" section and contamination of\r\nthe drilling fluid system resulted in 51.7 days of unscheduled events during\r\nthe course of the well. The final solution was to abandon the contaminated\r\nsection and make a sidetrack from 3760 m. The well was drilled with seawater\r\nand bentonite pills down to 1008 m and with PHPA/KCl/glycol/polymer mud (ANCO\r\n2000) from 1008 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe prognosed Permian / Devonian sand\r\nunits similar to Embla field, were not seen. Oil shows were observed in the\r\nEkofisk, Tor and Hod Formations, typically associated with fractures, but the\r\nchalks were not of reservoir quality. The well penetrated a 612 m\r\npre-Cretaceous section in which the Late Jurassic was absent. Top Carboniferous\r\nwas set at 4055 m. Sandstone intervals were present, but there were no shows\r\napart from an isolated show in a black claystone at 4119 m in the\r\nCarboniferous. Organic geochemical analyses of cuttings showed that the\r\nCarboniferous shales and coal beds were mainly Type III with a poor to fair\r\npotential for gas only. Four cores were cut, three from the interval 3038 m in\r\nthe Våle Formation to 3070 m in the Ekofisk Chalk Formation and one in","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"857","properties":{"OBJECTID":857,"wlbNpdidWellbore":2167,"wlbName":"34/7-22","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 34/7-22 is located between the\r\nGullfaks and Snorre fields on Tampen Spur in the Northern North Sea. The main\r\nobjective was to prove hydrocarbons and reservoir quality of a Brent Group\r\nprospect named the STWB prospect, defined by structural closure towards east\r\nand north, dip closure towards south, combined with fault seal against the Main\r\nTordis Fault (MTF) towards west. Sands within Paleocene, Cretaceous, and Late\r\nJurassic were secondary objectives.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 34/7-22 was spudded with the\r\nsemi-submersible installation West Delta on 15 August 1993 and drilled to TD at 2507 m in the Early Jurassic Drake Formation. Since possible shallow gas\r\nlevels had been predicted, a 9 7/8" pilot hole was drilled. The Nordland\r\nGroup consisted mainly of claystone except for the sandy Utsira Formation,\r\nwhich came in at 907 m. On the seismic, top Hordaland was interpreted to\r\ncoincide with a structural high which was considered to be a clay diapir. The\r\n"clay diapir" consisted, however, almost entirely of sandstone which\r\npartly belongs to the Utsira Formation and the upper part of the Hordaland\r\nGroup. The unexpected large amounts of sand caused operational problems due to\r\ninstability and the drill string got stuck at 1086 m, on 17 August. The string\r\nwas backed off and the well was re-spudded on 18 August. The casing program was\r\nre-designed to penetrate and stabilize the sandy Utsira Formation and Hordaland\r\nGroup with a weighted mud system. After re-spud, drilling commenced as planned.\r\nThe well was drilled with spud mud down to 1329 m, and with KCl mud with glycol\r\nfrom 1329 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eNo sand or hydrocarbons were found within\r\nthe Paleocene and Cretaceous (Campanian) intervals, but at 2178.5 m, a water wet\r\nIntra-Draupne Formation sand was penetrated. At 2184 m the Heather Formation\r\nwas encountered with a thickness of 40 m, 31m thicker than prognosed. Top\r\nreservoir, corresponding to Top Tarbert Formation, B","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"858","properties":{"OBJECTID":858,"wlbNpdidWellbore":2179,"wlbName":"34/8-10 S","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 34/8-10 S was drilled to appraise\r\nthe 34/8-1 Visund discovery on Tampen Spur in the Northern North Sea. The objectives\r\nwere to confirm the presence of mobile hydrocarbons and the pressure regime in\r\nthe SI segment (Statfjord Formation); to confirm the absence of free gas cap\r\nand also pressure regime and fluid composition in the NI segment (BrentGroup);\r\nto improve stratigraphic control of base Cretaceous, the A-Central Fault, top\r\nStatfjord and top Lunde; and to characterise the Lunde B/C aquifer and pressure\r\nregime.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 34/8-10 S was spudded with\r\nthe semi-submersible installation Polar Pioneer on 28 September 1993 and\r\ndrilled to TD at 3470 m (3316 m TVD) in the Late Triassic Lunde Formation. The\r\nwell was drilled with an angle of 37 degrees through the reservoir to achieve\r\nthe objectives. It was drilled with seawater and hi-vis pills down to 1358 m, and\r\nwith Anco 2000 glycol mud from 1358 m to TD. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well penetrated oil-bearing\r\nsandstones in all the potential reservoirs: Brent-NI, Amundsen-SI, Statfjord-SI\r\nand Lunde-SI. The Brent Group was penetrated at 2879.5 m in a heavily faulted\r\narea. It was represented by the Rannoch Formation from 2879.5 to 2885 m and by\r\nEtive Formation from 2888 to 2896.5 m with a fault slice identified as Drake\r\nFormation in between (2885-2888 m). A gross reservoir thickness of 14 m was\r\ndefined, giving a net pay of 10 m. The pressure in the Brent Group was found to\r\nbe higher than previously documented, and in addition the oil was of a lighter\r\ncomposition. No free gas cap was found in the Brent sandstones.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe Amundsen Sandstone was not expected\r\nto be penetrated as the well was planned to cut the A-Central fault ve","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"859","properties":{"OBJECTID":859,"wlbNpdidWellbore":2180,"wlbName":"34/8-11","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 34/8-11 was drilled to appraise the\r\n34/8-1 Visund discovery on Tampen Spur in the Northern North Sea. The main\r\nobjective was to verify the extension of the Brent reservoir and fluid type\r\nencountered in Well 34/8-8.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 34/8-11 was spudded with\r\nthe semi-submersible installation Polar Pioneer on 10 December 1993 and drilled\r\nto TD at 3140 m in the Early Jurassic Cook Formation. No significant problem\r\nwas encountered in the operations. The well was drilled with seawater and\r\nhi-vis pills down to 1295 m, and with the ANCO 2000 glycol mud system from 1295\r\nm to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eA 1.5 m thick section of the Draupne\r\nFormation was encountered at 2852.5 m on top of a 15 m thick Heather Formation\r\nat 2854 m. The Brent Group was encountered at 2869 m. The Brent Group contained\r\noil-bearing sandstones in the Tarbert, Ness, Etive and Rannoch Formations. A\r\ngross Brent reservoir thickness of 142 m was defined, giving a net pay of 69.4 m.\r\nFrom MDT pressures and logs an OWC was indicated between 2960 and 2965 m in the\r\nRannoch Formation, however, moveable oil appears to be present all through the\r\nRannoch. Reservoir geochemistry of core extracts indicate a shift from\r\nunaltered oil to slightly biodegraded residual oil somewhere between 2969 m and\r\n2986 m. Good oil shows were recorded on the cores down to 3005 m otherwise no\r\nother oil shows were described in the well.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eEight cores were cut in succession from\r\n2859 to 3008 m, covering the lower half of the heather Formation and all of the\r\nBrent Formation. The core depth shifts relative to the logs were in the range\r\n-1.5 m to - 2.0 m; except for core no 4, which had a core-log shift of + 0.125\r\nm. \u00A0MDT fluid samples were taken at","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"860","properties":{"OBJECTID":860,"wlbNpdidWellbore":2182,"wlbName":"6507/7-10","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 6507/7-10 was the third and last of\r\nthe commitment wells to be drilled on PL 095. The well was located 200 km off\r\nthe mid-Norwegian coast and approximately 7.5 km north of the Heidrun Field.\r\nThe structure drilled was a graben down faulted from the Heidrun Field. The\r\nprimary objective of well 6507/7-10 was to test the presence of commercial\r\nhydrocarbons in Middle Jurassic Fangst Group Sandstones. The Early Jurassic\r\nTilje and Åre Formations were secondary objectives. Both Tilje and Are\r\nformations would be encountered below the known hydrocarbon contacts observed\r\nwithin the Heidrun and Heidrun Nord Fields, and the potential for hydrocarbons\r\nin these formations would depend on fault seal for closure. TD was planned in\r\nTriassic strata or 4000 m.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well was spudded with the\r\nsemi-submersible installation Arcade Frontier on 28 September 1993 and drilled\r\nto TD at 3309.5 m in the Triassic Grey Beds. The well was drilled with spud mud\r\ndown to 1150 m and with KCl/polymer mud from 1150 m to TD. \u003c/p\u003e\r\n\r\n\u003cp\u003eA 56 m thick Fangst section (Garn, Not\r\nand Ile) was penetrated with top Fangst at 2507 m, 61 m below prognosed top.\r\nThe BÅt group consisted of 42.5 m Ror Formation, 155 m Tilje Formation and 412\r\nm of Åre Formation. Good sands with average log porosities from 24% to 29% were\r\nfound in the Garn, Ile, Tilje, and Åre Formations. Unexpected Late Jurassic\r\n(Spekk and Melke) sections with thin sand zones with traces of hydrocarbons\r\nwere penetrated. Apart from these shows all sands in the well were found 100%\r\nwater wet. Geochemical analyses of an extract from 2477 m in the thin Melke\r\nFormation sand indicated that the hydrocarbons here were generated in a more\r\nmature source rock (%Ro = 0.75 - 0.80) than the in-situ shales at this level\r\n(Ro = 0.6%). \u003c/p\u003e\r\n\r\n\u003cp\u003eThree cores were cut with 85%, 80% and\r\n100% recovery respectively. The two first cores were cut in the thin Late\r\nJurassic sand zones (2448.5-2454.5 m and 2476.5-2481.0","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"861","properties":{"OBJECTID":861,"wlbNpdidWellbore":2183,"wlbName":"6507/8-6","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 6507/8-6 was drilled on a\r\nstructure ca 4.5 km NE of the Heidrun Nord 6507/8-4 Discovery well. The main\r\nobjective was to test the potential for hydrocarbons in Middle and Early\r\nJurassic sandstones in the Fangst and BÅt Groups.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well was spudded with the\r\nsemi-submersible installation Deepsea Bergen on 29 August 1993 and drilled to\r\nTD at 2850 m in the Triassic Red Beds. After setting the 13 3/8 casing shoe at\r\n1605 m 213.5 hours rig time was spent due to problems with running the pack off\r\nassembly. The interval from seafloor to 1605 m was logged by MWD only. No other\r\nsignificant deviation from planned operations occurred. The well was drilled\r\nwith seawater and hi-vis pills down to 685 m and with gypsum/PAC from 685 m to\r\nTD. \u003c/p\u003e\r\n\r\n\u003cp\u003eIn addition to sandstones of Middle and\r\nEarly Jurassic age also Melke sandstones of Late Jurassic age were encountered.\r\nThe well was 100% water wet all through. Fluorescence but no cut was observed\r\nin two samples from 2073 (siltstone/limestone in base intra-Melke sandstone)\r\nand 2232 m (sandstone in Tilje Formation). One conventional core was cut in the\r\ninterval 2054 m to 2072 m in the intra-Melke sandstone. Only 5.3 m (24.9%) was\r\nrecovered. One segregated sample was taken at 2049.0 m in the intra-Melke\r\nsandstone. Both chambers contained water and mud filtrate.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 9\r\nOctober 1993 as a dry well.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was performed in the\r\nwell.\u003c/p\u003e\r\n\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"862","properties":{"OBJECTID":862,"wlbNpdidWellbore":2193,"wlbName":"6610/3-1 R","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 6610/3-1 is located ca 80 km\r\nsouthwest of the Røst Island in the Lofoten archipelago of Northern Norway. The\r\nmain objective was to test the hydrocarbon potential in the Early Jurassic\r\n(Tilje Formation) sandstones. A secondary objective was to test the possibility\r\nof development of sandy fans from Early Tertiary (Paleocene) to Early\r\nCretaceous. The secondary objective had been fulfilled by drilling of the\r\nprimary entry 6610/3-1, which was temporarily abandoned in February 1993 due to\r\nproblems induced by severe weather conditions. The re-entry was done to fulfil\r\nthe primary objectives.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 6610/3-1R is the re-entry of\r\nwell 6610/3-1. It was entered with the semi-submersible installation Ross Isle\r\non 15 September 1993 just below the 13 3/8" casing shoe in well 6610/3-1\r\n(kick-off point at 1750 m in intra-Tang sandstone). Well 6610/3-1R was drilled\r\nto TD at 4200 m in the Triassic Red Beds. No significant technical problems\r\nwere encountered during drilling. The well bore was drilled with ANCO 2000 mud\r\nfrom kick-off to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe Tilje Formation was encountered from\r\n3771 m to 3935 m with sandstone interbedded with siltstone and with limestone\r\nand claystone stringers. The sandstone was mostly fine-grained and mostly\r\nsilica and calcite cemented. An FMT pressure log was run, but no gradient could\r\nbe established due to tight/impermeable Formation. The well penetrated three\r\nsource rock formations: the Spekk Formation (3534 m to 3614 m), the Melke\r\nFormation (3614 m to 3705 m, and the Åre Formation coals (3935 m to 4147 m).\r\nModerate to minor shows of unproducible character were detected at scattered\r\nintervals in the Lange Formation. These were indicated by wet gas occurrences,\r\nsediment extracts and oil recovered through mud injection in a test interval.\r\nTrace shows were also recorded on claystones/limestones and silty layers in the\r\nSpekk and Melke Formation. No producible oil or gas was en","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"863","properties":{"OBJECTID":863,"wlbNpdidWellbore":2194,"wlbName":"2/5-10 A","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eExploration well\r\n2/5-10 is located in the Central Graben on the Steinbit Terrace. The well was\r\ndrilled with Late Jurassic sandstone of Oxfordian age, in a combination trap\r\nwith structural and dip closing elements, as the primary target. Secondary\r\ntargets were the Middle Jurassic Bryne Formation in the same combination\r\ntrapping configuration, while the Late Cretaceous Chalk and the Lower\r\nCretaceous Cromer Knoll Group were stratigraphic trap targets. After reaching\r\nTD evaluation of the cores and electric logs concluded that a fault had been\r\nintercepted within the main Jurassic target, justifying a sidetrack in search\r\nof a better pay zone. Well 2/5-10 was therefore plugged back in and well 2/5-10\r\nA sidetracked. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 2/5-10 was\r\nspudded with the semi-submersible installation "Polar Pioneer" on 23\r\nMay 1993 and drilled to TD at 4701 m in rocks of the Triassic Smith Bank\r\nFormation. The well was drilled with sea water and hi-vis sweeps down to 865 m,\r\nwith KCl/Polymer mud from 865 m to 4235 m, and with HPHT/Polymer mud from 4235\r\nm to TD. Shallow gas was encountered after drilling the 8 1/2" pilot hole,\r\nprior to opening up the hole to 26" and running 20" casing. In order\r\nto ensure a good 20" casing cement job without compromising rig safety it\r\nwas decided to plug back the gas bearing zone and set 20" casing at 509m,\r\n291m shallower than originally planned 800m. To avoid gas migration the cement\r\nslurries for the 20" and 13 3/8" were redesigned with gas tight\r\ncement (microblock added). \u003c/p\u003e\r\n\r\n\u003cp\u003eTop reservoir was\r\nencountered at 4582 m, 174 m deeper than prognosis due to complex geology and\r\nhigher than expected shale interval velocities in the Late Jurassic. The main\r\npart of the Late Jurassic sandstone target was removed by faulting, and\r\nTriassic strata were encountered 5 m below top reservoir through a fault plane.\r\nThe Late Jurassic sandstone was highly affected by the faulting,","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"864","properties":{"OBJECTID":864,"wlbNpdidWellbore":2205,"wlbName":"6204/11-1","wlbHistory":"\u003cb\u003e\r\nGeneral\r\n\u003c/b\u003e\r\n\u003cp\u003e\r\nThe main objectives for well 6204/11-1 was to test commercial reserves of hydrocarbons in sandstones of Middle Jurassic age and in sandstones of Turonian age. A secondary objective was to test the play concept and possibly prove hydrocarbons in an Upper Jurassic sandstone.\r\n\u003c/p\u003e\r\n\u003cb\u003e\r\nOperations and results\r\n\u003c/b\u003e\r\n\u003cp\u003e\r\nWell 6204/11-1 was spudded on 10 October 1994 with the semi-submersible rig \"Deepsea Bergen\" and drilled to 2966 m in the Triassic Grey Beds. The 30\", 20\" and 13 3/8\" casings strings were successfully set. The 9 5/8\" casing was planned but left out. The 12 1/4\" hole was drilled using a packed bottom hole assembly. The vertical hole was obtained at high weight on bit and reduced bottom hole assembly failures due to shock / vibration effects. No drilling problems were encountered. The well was drilled with pre-hydrated bentonite (PHB) to 540 m, and KCl polymer mud from there to TD.\r\n\u003cbr\u003e\r\n\u003cbr\u003e\r\nThe well proved, with some exception, the geological model. Sandstones of both Upper and Middle Jurassic age were encountered.\r\n The well was however terminated in Triassic sediments not in the basement as prognosed.\r\n\u003cbr\u003e\r\nThe well proved hydrocarbons with low saturation from 2029 to 2046 m in sandstone of Turonian age. The top of the Jurassic prospect was penetrated 23 m deeper than prognosed and proved to be gas bearing. The gas-water contact was found at 2792.5 m TVD RKB (2769.5 m TVD MSL). Good oil shows were observed in the cores below the gas-water contact and measurements from the cores indicate immature oil with low saturation below the gas - water contact.\r\n\u003cbr\u003e\r\n\u003cbr\u003e\r\nSix cores were cut, three in the Cretaceous and three in the Jurassic. FMT and RCI wire line samples were taken at 1938 m (gas and mud filtrate), 2032.5 m (mud filtrate and small amounts of oil), 2043.8 m (mud, mud filtrate, and oil film), and 2787 m (mud filtrate and gas).\r\n\u003cbr\u003e\r\n\u003cbr\u003e\r\nThe well was plugged and abandoned on 14 November 1994 as as a gas discovery.\r\n\u003c/p\u003e\r\n\u003cb\u003e\r\nTesting\r\n\u003c/b\u003e\r\n\u003cp\u003e\r\nNo drill stem te","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"865","properties":{"OBJECTID":865,"wlbNpdidWellbore":2207,"wlbName":"6305/12-2","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 6305/12-2 is located in the\r\nsouthwestern part of block 6305/12 in the Slørebotn Sub-basin. The primary\r\nobjective \u003c/p\u003e\r\n\r\n\u003cp\u003ewas to test the hydrocarbon and reservoir\r\npotential of a stratigraphic Cretaceous Wedge Prospect of anticipated Aptian to\r\nCenomanian age. The secondary objective was to test the reservoir quality and\r\nhydrocarbon potential of a structural closure at the Base Cretaceous level\r\ncalled the E-prospect.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 6305/12-2 was spudded with\r\nthe semi-submersible installation Deepsea Bergen on 16 October and drilled to\r\nTD at 3162 m in the metamorphic basement. A kick occurred at 2973 m, in the top\r\nof Middle Jurassic sandstone, requiring increases in mud density to 1.45 sg and\r\nresulting in lost circulation further up the hole, most likely into the\r\nPaleocene Sandstone unit. After 7" liner was set to 2635 m background gas\r\nup to 10.5 %, formation gas peaks to 13.6 % and pumps-off gas peaks to 15.5 %\r\nmade it necessary to increase the mud density in stages from 1.50 sg to 1.73\r\nsg. The one successful FMT point, at 3000 m, showed formation pressure to be\r\n1.69 sg in a very tight sandstone. The kick and technical problems related to\r\ncoring led to two technical sidetracks that should be considered when evaluating\r\nlogs and cores: the first from 2670 m to 2974 m and the second from 2910 m to\r\nfinal TD. The well was drilled with seawater and bentonite down to 437 m and\r\nwith the ANCO-2000 KCl/glycol mud system from 437 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe mapped stratigraphic wedge supposed to\r\nbe of Cretaceous age was encountered at 2970 m and proved to be Middle Jurassic\r\nsediments. The sediments were gas bearing, but with extremely poor reservoir\r\nproperties. The possible reservoir in the E - prospect consisted of metamorphic\r\nbasement with no significant porosity or permeability. Moderate shows were\r\nobserved in the Late Cretaceous, in sandstone stringers from 2530 m to 2580 m\r\nand in limestone and dolomite stringers","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"866","properties":{"OBJECTID":866,"wlbNpdidWellbore":2222,"wlbName":"3/4-1","wlbHistory":"\u003cb\u003e\r\nGeneral\r\n\u003c/b\u003e\r\n\u003cp\u003e\r\nWell 3/4-1 was the first well drilled in block 3/4 and was designed to penetrate and evaluate all potential hydrocarbon bearing formations above the Permian Zechstein Salt. The trap that was evaluated is a four way structural closure defined at Base Cretaceous level, formed by salt induced basin inversion, producing the present anticlinal configuration. The structure was identified using 2D seismic data in 1992, but, at that time, the structural configuration of the prospect and the composition of the clastic package could not be defined. Further geophysical, geological and geochemical studies were undertaken to better define the structure and Well 3/4-1 was drilled to help define the nature of the clastic package found in this part of block 3/4.\r\n\u003c/p\u003e\r\n\u003cp\u003e\r\nThe primary reservoir objective was the Upper Jurassic, shallow marine sandstone deposits contained in the hanging wall clastic package of the Coffee Soil Fault. Middle Jurassic sandstones were regarded as secondary objectives. \r\n\u003c/p\u003e\r\n\u003cb\u003e\r\nOperations and results\r\n\u003c/b\u003e\r\n\u003cp\u003e\r\nExploration well 3/4-1 was spudded with the jack-up installation Maersk Gallant on 11 January 1994 and drilled to TD at 3107 m, 18 m into the Permian Zechstein Salt Group. The well was drilled with seawater and bentonite sweeps down to 506 m and with \"ANCO 2000\" (ca 3% \"ANCO 208\" glycol additive) from 506 m to TD.\r\n\u003c/p\u003e\r\n\u003cp\u003e\r\nThe top of the Hordaland at 1103 m and top of the Rogaland at 2317 m were 17 m shallow and 16 m deep respectively, in relationship to prognosed tops. The top of the Chalk (Shetland Group) 2415 m was 10 m shallower than prognosed, and was 252.5 m thick, 52.5 m thicker than prognosed. No hydrocarbon bearing intervals were found in the Chalk section as had been anticipated. A total of 295 m of Jurassic section was penetrated, versus a prognosed 450m, with 184m of reservoir quality sandstones (versus a prognosed 80m). The Upper Jurassic Ula Sandstone was 184 m thick, 104 m thicker than prognosed, and was dominantly clean sand. There were no free ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"867","properties":{"OBJECTID":867,"wlbNpdidWellbore":2223,"wlbName":"30/9-15","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 30/9-15 is\r\nlocated in the Eastern part of Block 30/9 on the Oseberg Sør Field. The primary\r\nobjectives of the well were to test the hydrocarbon potential of the Brent\r\nGroup, Cook, and the Statfjord Formations on the J-north compartment with\r\nrespect to commercial volumes and future relinquishment decisions. It was not\r\npossible to locate a vertical well on the J-north compartment which could test\r\nall three reservoir levels in an optimal position. Priority was therefore given\r\nto the Brent reservoir, and the well location was chosen in order to prove\r\nhydrocarbons in the Brent Group, leaving a minimum of untested hydrocarbon\r\npotential in the lower Ness reservoir up dip of the well. Secondary objectives\r\nwere to penetrate the Cook and Statfjord Formations shallower than the water up\r\nto (WUT) top Statfjord in well 30/9-5 (2564 m MSL).\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 30/9-15\r\nwas spudded with the semisubmersible installation \"West Vanguard\" on\r\n7 December 1993 and was drilled to a&\r\ntotal depth of 2764 m in the Early Jurassic Statfjord Formation. The\r\nwell was drilled with sea water and hi-vis pills down to top of 12 1/4\"\r\nsection at 936 m, and with ANCO 2000 mud with glycols from 936 to TD. The Brent\r\nGroup was encountered at 2249 m and was proven to be oil bearing in the lower\r\nNess Formation, with an ODT at 2348.5 m. The ORE (Oseberg/Rannoch/Etive)\r\nFormations contained residual oil. The Cook Formation was proven water bearing\r\nthough moderate to weak shows were recorded from sidewall cores taken over the\r\ninterval 2465.5 - 2475.5 m. The Statfjord Formation was proven water bearing.\r\nThree conventional cores were recovered from the intervals 2240 m to 2250 m\r\n(Hardråde, Åsgard, and Ness Formations), 2256m to 2281 m (Ness, ORE, and Drake\r\nFormations), and 2283 m to 2306 m (Drake Formation). A wire line MDT sample of\r\nacceptable quality was recovered from 2249.9 m in the oil zone in the Ness\r\nFormation. The well was plugged back and permanently aba","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"868","properties":{"OBJECTID":868,"wlbNpdidWellbore":2244,"wlbName":"24/9-5","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 24/9-5 was drilled in a\r\nlocation SW of the Heimdal field, ca 5 km from the UK border. It was programmed\r\nto test two primary sandstone prospects in the Late Paleocene. The lower\r\nobjective was the Hermod Formation and the upper objective was sandstones\r\nwithin the Balder Formation. The Hermod Formation prospect was a mapped\r\nisochron thick with a small area of structural closure at Top Sele Formation.\r\nThe Balder Formation prospect was mapped as an isochron thick with an associated\r\nseismic amplitude anomaly and was primarily regarded as a stratigraphic trap. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 24/9-5 was spudded with the\r\nsemi-submersible installation West Delta on 7 December 1993 and drilled to TD\r\nat 2860 m in the Late Cretaceous Jorsalfare Formation. No significant problem\r\nwas reported from the operations. The well was drilled with seawater down to\r\n581 m, with KCl/PAC/PHPA from 581 m to 1941 m, and with KCl/PAC/PHPA/glycol\r\nfrom 1941 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe Balder Formation was encountered at\r\n1964 m. A gross oil bearing Intra Balder Formation sandstone interval of 7.1 m\r\nwas encountered at 2011 m. Net sandstone was 6.3 m of which 5.9 m was in a\r\nsingle massive unit. Petrophysical analysis gave porosities of 35 - 40% in the\r\nmassive sandstone unit with an average SW of 22.2%. Base of the reservoir was\r\nencountered at 2018 m, which was found to be an oil-down-to water contact.\r\nSamples from the FMT tool indicated the reservoir fluid to consist of 32-34 deg\r\nAPI oil with a GOR of 91 Sm3/Sm3. Pressure gradient analysis gave a free water\r\nlevel at 2031.5 m (2028.0 m TVD). Geochemical analysis of the oil sample\r\nindicated minor biodegradation had taken place. The Sele Formation was\r\nencountered at 2031 m with 47 m net sandstone in two Hermod Formation sequences.\r\nThe upper sequence was encountered at 2049 m and the lower at 2098 m. These\r\nsandstones proved to be water bearing with no shows. A thin sandstone at 2045.5\r\n- 2047 m, just above the u","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"869","properties":{"OBJECTID":869,"wlbNpdidWellbore":2248,"wlbName":"30/12-1","wlbHistory":"\u003cb\u003e\r\nGeneral\r\n\u003c/b\u003e\r\n\u003cp\u003e\r\nWell 30/12-1 is located ca 12 km south of the 30/9-16 discovery well on the Oseberg Field complex. It was drilled to reduce uncertainties about hydrocarbon migration in the eastern part of the block. The primary objectives of the well were to test the hydrocarbon potential of the Middle Jurassic Tarbert Formation with the Ness-Oseberg-Rannoch-Etive Formations and the Early Jurassic Cook and Statfjord Formations.\r\n\u003c/p\u003e\r\n\u003cb\u003e\r\nOperations and results\r\n\u003c/b\u003e\r\n\u003cp\u003e\r\nExploration well 30/12-1 was spudded with the semi-submersible installation \"West Vanguard\" on 6 January 1994 and drilled to TD at 3641 m in the Early Jurassic Statfjord Formation. The well was drilled with seawater and bentonite hi-vis sweeps down to 1130 m and with \"ANCO 2000\" mud from 1130 m to TD.\r\n\u003c/p\u003e\r\n\u003cp\u003e\r\nThe Tarbert Formation was penetrated at 2903 m and was found to be 86 m thick in this well. The Brent Group, the Cook Formation, and the Statfjord Formation were found to be water bearing. Three conventional cores with 65 to 99 % recovery were cut in sandstone with thin coal beds in the interval 2901 m to 2970 m. Core number 1 included the lowermost two metres of the Heather Formation, otherwise all cores were cut in the Tarbert Formation. No fluid samples were taken. The well was permanently abandoned as a dry well on 7 March 1994. \r\n\u003c/p\u003e\r\n\u003cb\u003e\r\nTesting \r\n\u003c/b\u003e\r\n\u003cp\u003e\r\nNo drill stem test was performed.\r\n\u003c/p\u003e\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"870","properties":{"OBJECTID":870,"wlbNpdidWellbore":2253,"wlbName":"2/4-18 R","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 2/4-18 R is located in the northern\r\npart of the block, on the eastern margin of the Feda Graben, Southern Norwegian\r\nNorth Sea. A number of wells originally operated by SAGA are located in this\r\narea on the Hidra Terrace, in the transition zone between the Hidra\r\nHigh-Steinbit Terrace to the NE, and the Feda Graben to the SW. The structural\r\nelements are separated by large NW-SE striking normal fault systems, forming\r\nseries of rotated and downstepping terraces towards the axis of the Central\r\nGraben. The main objective of well was to test the reservoir potential of the\r\nLate Jurassic in a down-dip position with respect to previous wells 2/4-14 and\r\n2/4-16. Secondary prospects were to be evaluated in the Late and Early\r\nCretaceous. Planned TD was 5042 m +/- 150 m.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 2/4-18 R was spudded with the\r\njack-up installation Maersk Guardian on19 February 1994 and drilled to TD at\r\n5310 m in the Late Jurassic Farsund Formation. Drilling went without\r\nsignificant technical problems and close to the planned time schedule. The well\r\nwas drilled with spud mud down to 521 m; with gel mud from 521 m to 1008 m;\r\nwith pseudo oil based mud (Novadrill with poly-alpha-olefins from 1008 m to\r\n3230 m, and with HI TEMP Polymer mud from 3230 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well penetrated 3048 m of sediments\r\nconfined to the Holocene-Eocene Nordland and Hordaland Groups. As in the\r\nprevious wells in the area, the uppermost 900 m was composed of sand and clay.\r\nThe rest was dominated by claystones with thin beds of limestone and sandstone.\r\nThe Lowermost Eocene-Early Paleocene Rogaland Group proved a thickness of 193\r\nm. The uppermost part was characteristically containing tuffaceous claystones.\r\nThe middle part was dominated by claystones with traces of limestone/dolomite,\r\nwhereas limestones and marls dominated the lower part. The Early Paleocene -\r\nLate Cretaceous Shetland Group had a thickness of 1113 m, and rested\r\nunconformable on the 252 m thick, Ear","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"871","properties":{"OBJECTID":871,"wlbNpdidWellbore":2256,"wlbName":"6608/10-4","wlbHistory":"\u003cb\u003e\r\nGeneral\r\n\u003c/b\u003e\r\n\u003cp\u003e\r\nThe main objective of well 6608/10-4 was to prove oil accumulation in the Middle Jurassic Sandstones in the Norne Northeast segment.\r\n\u003c/p\u003e\r\n\u003cb\u003e\r\nOperations and results\r\n\u003c/b\u003e\r\n\u003cp\u003e\r\nWildcat well 6608/10-4 was spudded on 15 December 1993 with the semi-submersible installation \"Ross Isle\" and drilled to a total depth of 2800 m, in rocks of the Lower Jurassic Åre Formation. The well was drilled entirely water based with sea water and hi-vis pills to 818 m, and Gyp/PAC mud from 818 m to TD.\r\nOil was encountered in the Middle Jurassic in the Melke Formation Sandstones and in the Garn Formation. One core was cut in the Cretaceous Nise Formation from 2091.0 m to 2095.5 m. Seven cores were cut in the interval from 2560.0 m in  the Melke Formation to 2709 m in the Åre Formation. Core recovery varied between 92% and 100%. Segregated FMT samples were taken in the Melke, Garn, and Ile Formations. The Melke samples contained mainly mud filtrate with small amounts/traces of oil and gas, the Garn samples failed due to lost seal, while the Ile samples recovered only mud filtrate. The well was plugged and abandoned on 7 March 1994 as an oil and gas discovery.\r\n\u003c/p\u003e\r\n\u003cb\u003e\r\nTesting\r\n\u003c/b\u003e\r\n\u003cp\u003e \r\nThree drill stem tests were performed in the well. One test, DST 1, tested the Tofte Formation in the interval 2635 to 2640 m. The second test, DST 2, tested the Garn Formation in the interval 2566.2 to 2582.2 m. The Melke Formation was tested in two steps: DST 3A in the intervals 2484.5 - 2499 and 2504 - 2514 m, and DST 3B in the interval 2524 to 2531 in addition to intervals 3A. During DST 1 and DST 3A and 3B no formation fluid were produced to the surface. DST 3 proved that the Melke Formation was tight with oil in place. DST 2 produced a maximum of 900 Sm3/D of oil with a density of 858 kg/m3 at standard conditions and 75000 Sm3/D of gas with a relative density of 0.648 (air = 1.0) through an 80/64\" (31.75 mm) choke. Minifrac tests were performed at the end of DST 1 and DST 2. The fracture closing pressures are eval","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"872","properties":{"OBJECTID":872,"wlbNpdidWellbore":2258,"wlbName":"9/2-4 S","wlbHistory":"\u003cb\u003e\r\nGeneral\r\n\u003c/b\u003e\r\n\u003cp\u003e\r\nThe main objective for the deviated well 9/2-4 S was to appraise commercial hydrocarbon reserves in the southern part of the Upper Jurassic Gamma structure on the Yme field. Further to prove continuation of the equivalent shallow marine sandstone seen in well 9/2-1, with similar reservoir properties, and finally, to gather data for improved seismic velocity analysis on the southern part of the Gamma structure.\r\n\u003c/p\u003e\r\n\u003cb\u003e\r\nOperations and results\r\n\u003c/b\u003e\r\n\u003cp\u003e\r\nAppraisal well 9/2-4 S was spudded with the semi-submersible installation \"DeepSea Bergen\" on 25 December 1993 and drilled to a total depth of 4417 m (3313 m TVD) in the Middle Jurassic Bryne Formation. No shallow gas was encountered in the top-hole section. The well was drilled to 4090m MD using water based mud with bentonite and bentonite/CMC EHV down to 647 m. The 17 1/2\" section (647 m to 2215 m) was drilled from the top to Early Cretaceous (Top Early Cretaceous at 1590 m) with KCl polymer mud, then converted to Anco 2000 mud by adding 3% glycol. Due to hole stability problems, the well was plugged back to 3755 m and a sidetrack was performed to TD at 4417m using ester based mud.\r\nThe top Sandnes Formation was penetrated 13.5 m higher than prognosed, and top reservoir sand 17.5 m higher than prognosed. The oil/water contact was not evident in this well. However, the results from the MWD/LWD gave no indication of a different OWC than anticipated in the well 9/2-1 (3210 m TVD MSL). The estimated Net/Gross for the reservoir section is 0.67, which is slightly less than for the 9/2 - 1 well. This is compensated by an increased thickness of high reservoir quality. One core was cut in the interval 4150m - 4168.5 m in the Sandnes Formation. A segregated FMT fluid sample from 4132.6 m gave an oil with density of 0.83 g/cc (at surface condition) and the four pressure measurements from the FMT-log gave an oil gradient of 0.70 g/cc. The well was tied back with 9 5/8\" casing and suspended 11 April 1994 as an oil appraisal. The well was then re-c","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"873","properties":{"OBJECTID":873,"wlbNpdidWellbore":2269,"wlbName":"30/3-6 S","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 30/3-6 S was drilled from the fixed\r\ninstallation Veslefrikk A. The Veslefrikk Field is located on the Brage Horst\r\nnorth of the Oseberg Field in the North Sea. The objective of 30/3-6 S was to\r\ntest the hydrocarbon potential in the I-prospect within the Brent, Dunlin and\r\nStatfjord reservoirs. The I-prospect is located on a down-faulted drag\r\nstructure just southwest of the main Veslefrikk field. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 30/3-6 S was spudded from slot\r\nnumber 20 on the fixed installation Veslefrikk A. The drilling phase was from\r\n26 December 1993 to 6 March 1994. The well was drilled in a southwesterly\r\ndirection from Veslefrikk A, and it has an S-shape wellbore with maximum\r\ninclination of 70°. Due to missing well logs for the upper part of the well,\r\nlithostratigraphy for this part of the well is not supplied.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well encountered hydrocarbons in the\r\nBrent Group down to the middle of the Oseberg Formation, and found a\r\nsignificantly thicker Jurassic sequence than anticipated. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eSeven cores were cut between 5241 m and\r\n5478.6 m, covering the Tarbert, Ness, and Etive Formations. Core recoveries\r\nfrom 86% to 100% was obtained. The RFT tool was run for pressure points, but no\r\nfluid samples were taken.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eExploration well 30/3-6 S is classified\r\nas a Brent Group oil and gas discovery. As the discovery was economic\r\nfavourably, the well was completed permanently as oil producer, and on 20 April\r\n1994 it was re-classified\u00A0 to development well 30/3-A-20.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eTesting\u003c/span\u003e\u003c/b\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eTwo tests were performed in the Oseberg\r\nFormat","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"874","properties":{"OBJECTID":874,"wlbNpdidWellbore":2285,"wlbName":"15/12-10 S","wlbHistory":"\r\n\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well is positioned on the western\r\nflank of the northern segment of the Varg Field, on a horst mapped at Top\r\nSleipner level. Thick Intra Heather sandstones present in the southern and\r\neastern segments of Varg were expected also in the northern segment. Over the\r\nhorst, Draupne/Heather shales were assumed eroded so that Intra Heather\r\nsandstones were present between BCU and Top Sleipner. These two horizons could\r\nbe mapped seismically, but the extent of sandstones could not be mapped. The\r\nwell was drilled to determine the extent and thickness of the Intra Heather\r\nsandstone reservoir over the northern segment of Varg and, if oil was\r\nencountered, to determine fluid characteristics and depth to the OWC. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 15/12-10 S was drilled\r\nfrom the S4 slot on the Varg subsea template using the semi-submersible\r\ninstallation Deepsea Bergen. It was spudded on 2 October 1996 and drilled\r\ndeviated to TD at 3550 m in the Triassic Skagerrak Formation. The deviation started\r\nat 250 m, building angle to 35 deg at 960 m and was then kept between 28 deg\r\nand 38 deg down to TD. No significant problems were encountered in the\r\noperations. The well was drilled with seawater down to 207 m, with\r\nseawater/PAC/CMC from 207 m to 1396 m, and with Ancovert oil based mud from\r\n1396 m to TD. No shallow gas was predicted and no shallow gas was found in the\r\nwell.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eDown to Top Shetland, the well was within\r\nprognosis, and penetrated the expected lithology. Below this level, the\r\nShetland limestone was thicker than expected, and Top Cromer Knoll and Base\r\nCretaceous was penetrated considerably deeper than prognosed (55 and 58 metres,\r\nrespectively). Below BCU, the well encountered Late Jurassic shales and\r\nsiltstones, and only 13 metres T","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"875","properties":{"OBJECTID":875,"wlbNpdidWellbore":2288,"wlbName":"24/9-6","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell\r\n24/9-6 was drilled to appraise the 24/9-5 discovery and is located 2.2 km to\r\nthe east of the 24/9-5 well location. Well 24/9-5 encountered a thin, 5.9 m net\r\nBalder Sandstone reservoir. It was considered not to be optimally placed for\r\nthe Balder Formation objective and no production tests were made. Instead well\r\n24/9-6 was drilled as an immediate appraisal in an optimum location. Mapping\r\nindicated that sandstone presence within the Balder Formation could be\r\nidentified by gross Balder Formation thickening and by an associated seismic\r\namplitude anomaly, believed to be a direct hydrocarbon indicator. Well 24/9-6\r\nwas located close to the centre of the Balder Formation interval thickening in\r\na position where the seismic amplitude anomaly was best developed\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations\r\nand results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eAppraisal\r\nwell 24/9-6 was spudded with the semi-submersible installation West Delta on 1\r\nFebruary 1994 and drilled to TD at 2255 m in the Paleocene Heimdal Formation.\r\nNo significant technical problems were reported from the operations. The well\r\nwas drilled with seawater down to 1279 m, with KCl/polymer/glycol from 1279 m\r\nto 1957 m, and with KCl/polymer mud from 1957 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe\r\nBalder Formation was encountered at 1917 m with two massive Intra Balder\r\nFormation sandstone sequences with a total net thickness of 49.5 m (prognosis\r\n25 m). The first Intra Balder Formation sandstone was encountered at 2010.5 m,\r\nthe second at 2034 m. A thin (0.5 m) oil-bearing\r\nsandstone was encountered at 2004.0 m just above the upper massive sandstone.\r\nThe upper massive sandstone was hydrocarbon bearing all through down to the\r\nbase at 2022 m, without any OWC seen. The lower\r\nmassive sandstone proved to be water bearing. Thin sandstones in the interval\r\n2029.0-2033.0 m had good shows on core. The highest known water was observed at\r\n2034.0 m. \u003c/p\u003e\r\n\r\n\u003cp\u003eAnalysis\r\nof a PVT sample from 2012.0 m showed the oil gravity to be 32 deg API with a\r\ngas/oil ratio (GOR) of 105 Sm3/Sm3. PV","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"876","properties":{"OBJECTID":876,"wlbNpdidWellbore":2296,"wlbName":"34/7-23 S","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 34/7-23 S is located on the Vigdis Field on Tampen\r\nSpur in the Northern North Sea. Located 5200 meters north-northwest of the H-Sentral\r\n34/7-21 oil discovery, the well was primarily designed to test for reservoir\r\npresence and hydrocarbons in the Top Draupne Sequence of Portlandian and\r\nRyazanian age. In the case of a discovery, pressure communication with well 34/7-21\r\nwould be tested. Secondary objectives of the well included lowermost Early\r\nCretaceous sandstones found oil bearing in 34/7-21, and intra Oxfordian\r\nsandstones which were found to yield oil in well 34/7-21 A. Both these\r\nsandstones are thin and below seismic resolution. An additional objective was\r\nto test the presence of sandstone in Paleocene.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 34/7-23 S was spudded with the semi-submersible\r\ninstallation Vildkat Explorer on 22 February 1994 and drilled to TD at 3375 m (2889 m TVD) in the Middle Jurassic Tarbert Formation. The subsea\r\nJurassic target location coincided with the pipeline which connects the Snorre\r\nTLP to the Statfjord C platform. To avoid any mechanical problems with the rigs\r\nanchors, the spud location was chosen to be located 1400 meters east of the\r\nBase Cretaceous target location and the borehole was designed as a westward deviated\r\nwell. Special H2S equipment was mobilized when H2S was observed during coring\r\nin the upper part of the reservoir. For operational reasons it was decided to interrupt\r\ncoring and take a FMT sample. An additional 10 meters were drilled from 3096\r\ndown to 3106 m to get a rathole for the FMT logging tool. This interval was\r\nthus not cored. The well was drilled with spud mud down to 1175 m, and with KCl\r\nmud with a polyalkyleneglycol additive (BP DCP 208) m from 1175 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eIn the Nordland, Hordaland and Rogaland\r\nGroups, the well penetrated mainly clay/claystone with some beds of sand,\r\nexcept for the sandy Utsira Formation between 955 - 1144 m (934 - 1114 m TVD).\r\nIn the Shetland Group clay stones wi","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"877","properties":{"OBJECTID":877,"wlbNpdidWellbore":2297,"wlbName":"2/11-10 S","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThe Hod Pod Prospect on the northeast\r\nflank of East Hod Field was first identified in 1991 as an anomaly on the\r\nexisting 2D data. Additional work and mapping defined the prospect as a\r\nstratigraphic trap in the upper chalk that appeared to be separate from the\r\nmain Tor reservoir of East Hod Field. The final well objective was defined by\r\n3D seismic data completed in April 1993 as two stacked (upper and lower) pods\r\nin the uppermost part of the chalk. They were believed to be allochthonous\r\nchalk in an upper pod (Ekofisk Formation) and a lower pod (uppermost Tor\r\nFormation).\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 2/11-10 S was drilled deviated\r\nfrom the centre slot (slot #4) of the Hod Platform with the Maersk Giant\r\njack-up rig. It was spudded 28 February 1994\u00A0 and drilled to TD at 4090 m (2920\r\nm TVD RKB) in the Late Cretaceous Hod Formation. Severe problems with running\r\nthe 13 3/8" casing were encountered, caused by mismatch in make between\r\ncasing running tool and the casing thread. When pulling out casing centralisers\r\nand stop rings were left in the hole. The junk could not be fished and the well\r\nwas sidetracked (2/11-10 S T2) from between 1397 m and 1547 m. The well was\r\ndrilled with seawater down to 382 m, and with Novadril oil based mud from 382 m\r\nto TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eSome oil shows were noted on claystone of\r\nthe Hordaland Group from 1725 m and down to 1960 m. Top of the chalk, Ekofisk\r\nFormation, came in at 3900.5 m (2820.7 m TVD RKB), and oil was present. The\r\nhigh porosities predicted from seismic prior to drilling were present in both\r\nthe Tor and Ekofisk Formations. The Ekofisk, however, had narrower pore throats\r\nthan the Tor resulting in lower permeability. Oil staining was present in the\r\ncored upper Tor reservoir from 3913 m down to 3957 m. An oil column height of\r\naround 28 m (above the 95% Sw entry point) was calculated from special core\r\nanalysis. The Tor Formation cored below 3957 m had lower porosity and\r\npermeability than the oil s","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"878","properties":{"OBJECTID":878,"wlbNpdidWellbore":2299,"wlbName":"6507/2-3","wlbHistory":"\u003cb\u003e\r\nGeneral\r\n\u003c/b\u003e\r\n\u003cp\u003e\r\nThe primary objectives of the well were to test the hydrocarbon potential of the Lysing and  Intra Lange Formations and further to\r\n test the reservoir quality and reservoir potential of a prospect lead in the Lyr Formation.\r\n\u003c/p\u003e\r\n\u003cb\u003e\r\nOperations and results\r\n\u003c/b\u003e\r\n\u003cp\u003e\r\nWell 6507/2-3 was spudded on 14th of March 1994, and reached a total depth of 3972 m RKB in the lowermost part of the Spekk Formation,\r\n on 22nd of April 1994. Water based mud was used with Spud mud to 1465 m RKB, \"ANCO 2000\" from there to 3141 m, and KCl/polymer from\r\nthere to TD.\r\nThe primary target, the Lysing Formation, was encountered from 2850m to 2891m RKB, and was water bearing.\r\nIt consisted of a fairly massive sandstone sequence. The secondary target, the Intra Lange Formation sandstone interval at\r\n 3250.5 -3281m RKB, comprised a heterogeneous reservoir with very poor reservoir properties and residual oil.\r\nTwo RFT runs were performed; one each in the Lysing and Lange Fm. A successful fluid sample was taken at 2852.6 m in\r\nthe Lysing Fm. In the Lange Fm. a fluid sample was attempted and finally aborted due to low reservoir permeability.\r\nNo reservoir was penetrated in the Lyr Fm. Two cores were cut from 2850 to 2891 m in the Lysing Formation and one from\r\n 3254 to 3264 m in the Lange Formation. The well was plugged and abandoned on 5th of may 1994 as a dry well with oil shows.\r\n\u003c/p\u003e\r\n\u003cb\u003e\r\nTesting\r\n\u003c/b\u003e\r\n\u003cp\u003e\r\nNo DST was performed\r\n\u003c/p\u003e\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"879","properties":{"OBJECTID":879,"wlbNpdidWellbore":2319,"wlbName":"15/9-20 S","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 15/9-20 S was drilled from\r\nthe Sleipner A platform on the Sleipner øst Field. It started off as\r\ndevelopment well 15/9-A-22, which was designed to provide gas production from\r\nthe Heimdal reservoir in the central part of the Sleipner Øst Field, and to\r\ncontribute with geological and reservoir technical data for optimal reservoir\r\nmanagement in this area. Due to unexpected geology in the deeper part of the\r\nwell the Cretaceous and below was reclassified to exploration well 15/9-20 S.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 15/9-20 S was spudded from the fixed\r\ninstallation Sleipner A on 16 February 1994 and drilled deviated to TD at 3624\r\nm in the Triassic Smith Bank Formation. No significant problems were reported\r\nfrom the operations. The well was drilled with seawater/PAC mud from below\r\n26" conductor to 506 m, with KCl/PHPA/PAC mud from 506 m to 1735 m, with\r\nKCl/PHPA/PAC/Glycol mud from 1735 m to 2928 m, and with ester mud from 2928 m\r\nto TD. No shallow gas was encountered.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well penetrated the Heimdal Formation\r\ntarget at 2931 m (2279.6 m TVD MSL), 11.6 m TVD deeper than prognosis. The\r\nHeimdal Formation was 104 m thick (71.2 m TVD) and proved to be gas filled as\r\nexpected. Under the Heimdal Formation the well drilled 204 m Late Cretaceous\r\nlimestone overlying 8 m Blodøks Formation. At 3247 m (2490.2 m TVD MSL) the\r\nwell drilled unexpected into Jurassic/Triassic sandy sediments, which proved to\r\nhave a 30 - 50 m TVD hydrocarbon leg.\u003c/p\u003e\r\n\r\n\u003cp\u003eFive conventional cores were cut from\r\n2940 - 3043 m in the Heimdal and into the top of the Tor Formation. A sixth\r\ncore was cut from 3216 - 3244 m, from base Hod Formation and into the Blodøks\r\nFormation. One RFT segregated sample was taken at 3272.6 m in the Skagerrak\r\nFormation.\u003c/p\u003e\r\n\r\n\u003cp\u003eWell bore 15/9-20 S was plugged back and\r\npermanently abandoned on 1 June 1994 as a gas discovery.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was perforated on wire line over\r\nthe interval 3229 - 3238 m ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"880","properties":{"OBJECTID":880,"wlbNpdidWellbore":2326,"wlbName":"34/7-23 A","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\u003cp\u003eExploration well 34/7-23 A was drilled in the H-Vest\r\nprospect as a sidetrack to well 34/7-23 S, located on the Vigdis Field on\r\nTampen Spur in the Northern North Sea. The main objective was to test for Top\r\nDraupne Sandstone reservoir presence within the Top Draupne Sequence of\r\nPortlandian and Ryazanian age and to test for an oil water contact. Secondary\r\nobjective was to test for reservoir presence and hydrocarbons in a seismic\r\nwedge in the middle Draupne Sequence. Additional targets were lowermost Late\r\nCretaceous and intra Oxfordian (Intra-Heather Formation) sandstones. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 34/7-23 A was kicked off from well\r\n34/7-23 S on April 8, 1994. The kick off point was at 2358 m (1968.5 m TVD) in\r\nthe upper part of the Shetland Group. The well was drilled westward deviated to\r\nTD at 3412 m (2769 m TVD) using the semi-submersible installation Vildkat\r\nExplorer. Drilling went without problem. During logging operations the FMT tool\r\ngot stuck at 3220 m and 60 hrs were spent fishing for it. The well was drilled with\r\nKCl mud with a polyalkyleneglycol additive (BP DCP 208) m from kick-off to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eIn the Shetland Group claystones with\r\nlimestone beds were penetrated. The condensed Cromer Knoll Group consisted of\r\nmarls, limestones and minor claystones. The Viking Group was encountered at\r\n3202.9 m (2619 m TVD). The topmost section was oil bearing Intra Draupne\r\nFormation sandstone from 3202.9 to 3246 m (2619 - 2649.1 TVD, 30.1 m gross).\r\nThis sandstone interval, which was the only sandstone interval encountered\r\nwithin the Draupne Formation, proved an ODT at 3246 m (2649.1 m TVD). No OWC\r\nwas identified on the logs or with the FMT-measurements. The Intra Draupne Formation\r\nSandstone reservoir had an estimated average log porosity of 22.4% and an estimated\r\naverage water saturation of 11.4%. The net gross ratio was 0.93. Below the\r\nreservoir, the Draupne Formation consisted of siltstones and claystones. The\r\nMiddle to Late Jurassic Heathe","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"881","properties":{"OBJECTID":881,"wlbNpdidWellbore":2355,"wlbName":"30/9-17","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 30/9-17 is located on the Bjørgvin\r\nArch south of the Oseberg Sør Field and North of the 30/9-16 K Oseberg Sør\r\nDiscovery. This is in the Northern North Sea. The well was drilled to clarify\r\nthe Oseberg Sør development strategy. The primary objective was to establish\r\nthe extent of the high-permeability Tarbert reservoir found in well 30/9-16.\r\nSecondary objectives were to test the lower Brent Group, the Cook Formation,\r\nand the Statfjord Formation. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 30/9-17 was spudded with the semi-submersible\r\ninstallation Treasure Saga on 3 March 1995 and drilled to 1408 m where the well\r\nwas temporarily plugged back. This was due to gas and mud flow from the annulus\r\nbehind 9 5/8" casing. All returns were to sea bed. The well was drilled\r\nwith spud mud from top to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe conventional logs run did not give\r\nconclusive information regarding the origin of the shallow gas. A CBL-log was\r\nrun, and two zones (832 - 831 m, 550 - 549 m) were selected for perforation and\r\ncementing in order to kill the well. The well was killed only after cement had\r\nbeen squeezed into the upper perforation interval. Hence, the origin of the\r\nshallow gas was suspected to be the Utsira Formation sand or in thinner sand\r\nbeds just above the Utsira Formation. No cores were cut and no wire line fluid\r\nsamples were taken in the well.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was suspended on 13 March 1995. The well did not reach its target, and replacement well 30/9-18 was spudded\r\nthe day after ca 50 m to the east-southeast.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was performed.\u003c/p\u003e\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"882","properties":{"OBJECTID":882,"wlbNpdidWellbore":2358,"wlbName":"25/11-18","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 25/11 -18 was\r\ndrilled to appraise the 25/11-15 Grane discovery drilled in 1991. The primary\r\nobjectives of 25/11-18 were to confirm beyond reasonable doubt recoverable oil\r\nreserves greater than 30 million Sm3 in the Heimdal Formation in the Grane\r\nDiscovery prior to initiating PDO activities; to obtain an Utsira formation\r\nwater sample and water production rates in order to design the water injection\r\nsystem for the Grane Field; to confirm top and base reservoir, reservoir development,\r\ncontinuity, and quality of Heimdal sand in order to reduce the uncertainties in\r\nthe resource estimates; to obtain velocity information as input to depth\r\nconversion model for the Grane Field; and to test coiled tubing drilling/coring\r\ntechnology as concept for future cost savings.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eAppraisal well\r\n25/11-18 was spudded with the semi-submersible installation "West\r\nVanguard" on 10 August 1994 and drill to a total depth of 1875 m in the\r\nLate Cretaceous limestones of the Hod Formation. Due to technical problems it\r\nwas not possible to do wire line logging at TD of the original well. The well\r\nwas technically sidetracked (25/11-18 T2) with kick-off at 1390 m. The well was\r\ndrilled with spud mud through the 36" and 24" sections down to 563 m,\r\nwith polymer mud through the 17 1/2" section to 1183 m, with "ANCO\r\n2000" mud from 1183 through the 8 1/2" section and into the slim 4\r\n1/8" section down to 1690 m where the hole was displaced to\r\n"AQUACOL" mud.& Drilling of\r\nthe 4 1/8" section continued with "AQUACOL" mud down to TD at\r\n1860 m. The technical sidetrack was drilled as a 6" hole to final TD at\r\n1875 m using KCl / Polymer mud. Coiled tubing drilling and coring and slim hole\r\nlogging was proven possible from an offshore floater with acceptable quality on\r\ngeological information. Operations, however, were hampered by problems related\r\nto junk and hole instability due to low mud","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"883","properties":{"OBJECTID":883,"wlbNpdidWellbore":2361,"wlbName":"30/9-16","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 30/9-16 was drilled on the Bjørgvin\r\nArch south of the Oseberg Fault block in the North Sea. The primary objective\r\nwas to prove hydrocarbon accumulations in the Tarbert Formation and the “NORE”\r\n(lower Brent Group) reservoir. Secondary objective was to test the hydrocarbon\r\npotential in the Cook Formation and Statfjord Group reservoirs within closure.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 30/9-16 was spudded with the\r\nsemi-submersible installation West Vanguard on 14 June 1994 and drilled to TD\r\nat 3550 m in the Early Jurassic Eiriksson Formation. No significant problem was\r\nencountered in the operations. The well was drilled with spud mud down to 165\r\nm, with ANCO 2000 mud from 165 m to 2668 m, and with KCl/polymer mud from 2668\r\nm to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eIntra Heather Formation sandstone came in\r\nat 2685 m and proved to be gas bearing with GOC at 2706 m, based on geochemical\r\ndata. Based on RFT pressure gradients the GOC is at 2711 m. The Tarbert\r\nFormation came in at 2718 m and was 101 m thick, 11 m thicker than prognosed. It\r\nwas oil-bearing with an OWC at 2764 m. There is a 10 bars pressure difference\r\nin the oil zone, between 30/9-13 S and 30/9-16. The 30/9-9 Lower Ness oil\r\ngradient is 14 bars higher than the 30/9-16 oil gradient. The water gradient is\r\nonly 1.5 bars higher than 30/9-13 S and three bars lower than 30/9-9. No hydrocarbons\r\nor shows were reported below OWC in the Brent Group, but weak shows, with gas\r\nshows at the top and oil shows below, were reported from the Statfjord Group at\r\n3455 – 3475 m. Further, down to TD, these shows disappeared or became localised.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eFour cores were cut. The three first were\r\ncut from 2694 m in the Heather Formation sandstone to 2796.4 m in the Tarbert\r\nFormat","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"884","properties":{"OBJECTID":884,"wlbNpdidWellbore":2366,"wlbName":"30/6-19 R","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 30/6-19 R is a re-entry of well\r\n30/6-19 between the Veslefrikk field and the 30/6-5 Oseberg East discoveries.\r\nThe objective of the re-entry was plugging and permanent abandonment.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 30/6-19 was re-entered with the semi-submersible\r\ninstallation West Vanguard on 15 May 1994. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was plugged and permanently\r\nabandoned on 25 May 1994.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eTesting\u003c/span\u003e\u003c/b\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo drill stem test was performed. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"885","properties":{"OBJECTID":885,"wlbNpdidWellbore":2373,"wlbName":"30/6-22 R","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 30/6-22 R is a re-entry of well\r\n30/6-22 on the 30/6-19 Oseberg East discovery. The objective of the re-entry\r\nwas plugging and permanent abandonment.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 30/6-22 was re-entered with the semi-submersible\r\ninstallation West Vanguard on 27 May 1994. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was plugged and permanently\r\nabandoned on 2 June 1994.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eTesting\u003c/span\u003e\u003c/b\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo drill stem test was performed. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"886","properties":{"OBJECTID":886,"wlbNpdidWellbore":2375,"wlbName":"30/6-21 R","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 30/6-21 R is a re-entry of well\r\n30/6-21 on the Oseberg Fault block in the North Sea. Well 30/6-21 tested oil in\r\nthe Brent Group and was suspended as a possible development well. The purpose\r\nof the re-entry was plugging and permanent abandonment.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 30/6-21 was re-entered with the\r\nsemi-submersible installation West Vanguard on 4 June 1994. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo new formation was drilled.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was plugged and permanently\r\nabandoned on 12 June 1994.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eTesting\u003c/span\u003e\u003c/b\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo drill stem test was performed. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"887","properties":{"OBJECTID":887,"wlbNpdidWellbore":2377,"wlbName":"34/11-1","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 34/11-1 was drilled on the Tjalve\r\nTerrace south-east of the Gullfaks Field in the northern North Sea. The main\r\nobjective for the well was to explore the hydrocarbon potential of the\r\nEarly-Middle Jurassic reservoirs within the Alpha structure, and to test the\r\ncurrent geological model for the Alpha structure and the Gullfaks Gamma\r\ncomplex. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 34/11-1 was spudded with the\r\nsemi-submersible installation Ross Rig on 7 July 1994 and drilled to TD at 4580\r\nm in Early Jurassic, possibly Late Triassic sediments of the Statfjord\r\nFormation. No significant problem was encountered in the drilling phase. Due to\r\nfish in the hole logs were not run below 2563 m. The well was drilled with bentonite/CMC\r\nEHV mud down to 1110 m, with ANCO 2000 mud with 3.2 - 4.4 % ANCO 208 glycols\r\nfrom 1110 m to 3932 m, and with ANCO THERM mud from 3932 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe top of the Brent Group was penetrated\r\nat 4045 m, 18 m lower than prognosed and proved to be gas/condensate bearing. A\r\ntrue gas-water contact was found at 4163 m at the base of the Ness Formation. Both\r\nthe Cook and the Statfjord Formations were water bearing. First trace of\r\nfluorescence in the well was reported in minor sandstones in the Lista\r\nFormation at 2115 m. Traces of light coloured fluorescence was observed\r\nsporadically on limestone down to top Brent Group, generally associated with\r\nelevated drill gas readings. At 3605 "oil film on shakers" was\r\nreported.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eA total of 131 m core was recovered in 12\r\ncores in the Brent Group from 4054 m to 4220 m. The core depths were from 1 to\r\n4 m shallow compared to the logger's depth. Segregated FMT samples were\r\ncollected at 4142 m in the Ness Formation and in the T","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"888","properties":{"OBJECTID":888,"wlbNpdidWellbore":2384,"wlbName":"6306/6-1","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 6306/6-1 was drilled on the Frøya\r\nHigh in the Møre I area off shore southern Mid Norway. The main objective was\r\nto prove HC accumulations in Late Jurassic Rogn Formation sandstones, the\r\nA-prospect.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 6306/6-1 was spudded with\r\nthe semi-submersible installation Ross Rig on 22 June 1994 and drilled to TD at\r\n1317 m in basement rocks. No significant problems were encountered in the\r\noperations. The well was drilled with bentonite and seawater down to 432 m and\r\nwith KCl/PAC mud from 432 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe Paleocene Egga sandstone unit was\r\nencountered at 604 m. The sandstones were rather silty; partly calcite\r\ncemented, and with reduced porosity due also to the presence of mica and\r\nglauconite. A 93 m thick Rogn Formation sandstone unit came in at 1158 m,\r\nsandwiched in Spekk Formation shales above and below. Under base Spekk a\r\nsequence of Middle Jurassic age (Fangst Group) was penetrated from 1267 m to\r\n1281 m. Sandstones with occasional interbeds of claystone/shale grading to\r\ncoals dominated this sequence. No shows were recorded in any section of the\r\nwell while drilling, and since only questionable sandstone extracts were found\r\nin post-well organic geochemical analyses the well is concluded as dry. Very\r\ngood source rocks are present in the well. The best source rock is seen in the\r\nupper Spekk section, which contain a typically marine anoxic, oil-prone Type II\r\nkerogen. The lower Spekk section has higher TOC, but is more terrestrial in\r\ncomposition and thus more gas/condensate -prone. Also the coaly shales and\r\ncoals of the Middle Jurassic have very good potential for mixed oil and gas.\r\nThe well is however immature all through with a vitrinite reflectance of about\r\n0.45 % Ro at TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eOne FMT run was performed in the Rogn\r\nFormation sandstone. Six pressure points gave a water gradient of 1.002 g/cm3.\r\nNo fluid sample was taken.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 5\r\nJuly as a dry hole.\u003c/p","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"889","properties":{"OBJECTID":889,"wlbNpdidWellbore":2389,"wlbName":"34/7-16 R2","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 34/7-16 R2 is located between the\r\nStatfjord and Snorre Fields on Tampen Spur in the Northern North Sea. It is a\r\nre-entry of well 34/7-16 R, which tested oil in the Brent Group and water in\r\nthe Statfjord Formation. The purpose of the re-entry was plugging and permanent\r\nabandonment.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 34/7-16 R was re-entered (34/7-16\r\nR2) with the semi-submersible installation Vildkat Explorer on 23 June 1994. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was plugged and permanently\r\nabandoned on 5 July 1994.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was performed.\u003c/p\u003e\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"890","properties":{"OBJECTID":890,"wlbNpdidWellbore":2390,"wlbName":"25/8-5 S","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThe main objective\r\nof Well 25/8-5 S was to test the presence of hydrocarbons in both the lower\r\nJurassic Statfjord Formation and in the Paleocene Heimdal Formation in the Elli\r\nProspect. The well was to be drilled as a directional well in order to\r\npenetrate the two objectives.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eExploration well\r\n25/8-5 S was spudded with the semi-submersible installation "Dyvi\r\nStena" on 21 July 1994 and was drilled as a deviated well to a total depth\r\nof 3395 m (3040.7 m TVD RKB / 2887.7 m TVD SS), 57 m into late Triassic\r\n(Rhaetian) sediments of the Smith Bank Formation. The well was drilled vertical\r\ndown to 1204 m before starting to build angle. It was drilled with seawater and\r\nhi-vis pills down to 1215 m and with KCl / polymer / PAC / Glycol from 1215 m\r\nto TD. \u003c/p\u003e\r\n\r\n\u003cp\u003eTop Heimdal\r\nFormation was penetrated at 2112.6 m (2050 m TVD SS) at an inclination of 33\r\ndegrees and an azimuth of 171 degrees and was found to contain oil. The\r\noil-water contact was estimated at 2158 m (2087 m TVD SS). The well found sands\r\nof the Vestland Group at 2836 m (2570 m TVD SS) water-wet and the second\r\nobjective, Statfjord Formation at 3040 m\r\n(2687.3 m TVD SS) water-wet. The inclination at top Statfjord was 53.6\r\ndegrees and azimuth 163.5 degrees. Top Triassic was correlated to be at 3338\r\n(2855.3 m TVD SS). The inclination was 55.2 degrees and azimuth 163.3 degrees\r\nat TD. The well was logged with LWD from 270 m to TD. The LWD included GR-Dual\r\nResistivity and Compensated Density/Neutron. Wire line logs were run from 1170\r\nm - 2291 m. Due to difficult hole conditions, it was not possible to run wire\r\nline logs below 2423 m. One core was cut in the Heimdal Formation from 2136 m\r\nto 2150 m and one core was cut in the Statfjord Formation from 3052 m to 3061\r\nm. A FMT fluid sample was taken at 2133.6 (2067 m TVD SS) m in the Heimdal\r\nFormation. The well was suspended on 22 September as an oil discovery (Jotun).\r\nIt was re-entered (25/8-5 S R) on 27 July 19","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"891","properties":{"OBJECTID":891,"wlbNpdidWellbore":2394,"wlbName":"2/7-30","wlbHistory":"\r\n\r\n\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 2/7-30 was drilled on the Edgar\r\nprospect in the Feda Graben ca 4 km north-east of the Eldfisk Field in the\r\nsouthern North Sea. The objective was to test a combined\r\nstructural/stratigraphic play first identified on seismic data as a\r\nhigh-amplitude anomaly within the Late Cretaceous (Maastrichtian) Tor\r\nFormation. The primary target for the 2/7-30 well was the upper Tor Formation\r\nas defined through seismic inversion modelling of the anomaly. The Paleocene\r\n(Danian) Ekofisk Formation was regarded as a secondary target, with two\r\npossible productive intervals, an upper zone of reworked Danian chalk and a\r\nlower zone dominated by reworked Maastrichtian deposits.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 2/7-30 was spudded with the jack-up\r\ninstallation Maersk Guardian on 27 February 1995 and drilled to TD at 3478 m in\r\nthe Late Cretaceous Hod Formation. No significant problem was encountered in\r\nthe operations. Coring in the well was performed with a "Security/DBS\r\ncoring system" where the inner barrel is oil filled. Apparently the base\r\noil in this system have contaminated some of the organic geochemical data from\r\nthe cores from the well. The well was drilled with seawater and\r\nbentonite/native clay down to 469 m and with a KCl/Pac/Glycol mud from 469 m to\r\nTD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe top Ekofisk Formation was encountered\r\nat 3150.1 m wire line depth, which was 17.4 m higher than prognosed. Both the\r\nupper and lower allochthonous intervals in Ekofisk Formation proved water wet,\r\ndespite some fair shows observed during drilling/coring. Porosity up to 25-28%\r\nand permeability close to 1 mD was obtained in these intervals. No pressure\r\ndata or formation fluid samples were collected due to the low","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"892","properties":{"OBJECTID":892,"wlbNpdidWellbore":2401,"wlbName":"34/7-19 R","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 34/7-19 R is a re-entry of well\r\n34/7-19 on the Vigdis Middle structure south of the Snorre Field. Well 34/7-19\r\nfound oil in the Tarbert Formation and was suspended in December 1991 as a\r\npossible development well. The purpose of the re-entry was plugging and\r\npermanent abandonment.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 34/7-19 was re-entered (34/7-19 R)\r\nwith the semi-submersible installation Vildkat Explorer on 6 July 1994 and plugged. \u003c/p\u003e\r\n\r\n\u003cp\u003eNo cores were cut and no wire line fluid\r\nsamples were taken.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 12 July 1994 as an oil appraisal.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was performed.\u003c/p\u003e\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"893","properties":{"OBJECTID":893,"wlbNpdidWellbore":2430,"wlbName":"30/8-1 S","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 30/8-1 S was drilled in the Viking\r\nGraben of the North Sea, just west of the Oseberg Fields.\u003c/span\u003e\u003cspan lang=EN-US\u003eThe objective was to \u003c/span\u003e\u003cspan\r\nlang=EN-GB\u003etest the hydrocarbon potential of the Jurassic Brent Group and\r\nStatfjord Formation. The well was committed to drill into the Hegre Group or to\r\na maximum depth of 5026 m TVD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 30/8-1 S was spudded with\r\nthe semi-submersible installation Treasure Saga on 1 November 1994 and drilled\r\nto TD at 4688 m in the Early Jurassic Amundsen Formation. No shallow gas was\r\nobserved in the well. A kick was taken at 4055 m, where 0.8 m3 was gained over\r\na 30 minute interval on drilling and 1.8 m3 gained on flow checking before\r\nshutting in the well. The kick was circulated out through the choke manifold\r\nand the well was killed with heavy mud. When logging the 12 1/4" section\r\nthe tools got stuck several times. On a short wiper trip to the 9 5/8"\r\ncasing shoe a 2.5 m3 kick was taken when circulating and 1.67 m3 while flow\r\nchecking. Again the well was killed with heavy mud. Frequent mud losses were\r\nexperienced in the final 8 3/8" section from 4332 to TD. The well was\r\ndrilled with spud mud down to 1360 m, with KCl/polymer mud from 1360 m to 4058\r\nm, and with Ancoterm High Temperature water based mud from 4058 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe main reservoir interval consisted of\r\nthe Middle and Lower Tarbert Formations, but the Ness and the ORE Formations\r\nwere also encountered. Hydrocarbons were encountered in the Tarbert Formation\r\nin a gas-down-to situation at 3687 m (3525.8 m TVD). Net sand is 109.9 m, with\r\nnet pay of 84.7 m. An additional thin hydrocarbon-bearing zone is indicated in\r\nsandstones of the Ness Formation at 3884 - 3888 m. The formation pressure data","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"894","properties":{"OBJECTID":894,"wlbNpdidWellbore":2431,"wlbName":"34/10-37","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 34/10-37 was drilled in the\r\nTampen Spur area, ca 8 km WNW of the Gullfaks Sør Field. The main objective of\r\nthe well was to test the potential for hydrocarbons in the sandstones of Middle\r\nJurassic age (Brent Group) on the Delta prospect. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 34/10-37 was spudded with the\r\nsemi-submersible installation Deepsea Bergen on 26 January 1995 and drilled to\r\nTD at 2873 m in the Early Jurassic Drake Formation. No significant problems\r\nwere encountered in the operations. The well was drilled with bentonite/CMC EHV\r\ndown to 1525 m, and with KCl/PAC from 1525 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 34/10-37 penetrated the Brent Group\r\nat 2613 m; about 58 m deeper than prognosed and the Tarbert Formation was\r\nfound to be absent. The Brent Group proved to be hydrocarbon bearing with an\r\nOWC at 2645 m (2622 m TVD MSL). \u003c/p\u003e\r\n\r\n\u003cp\u003eTwo conventional cores were cut from 2626\r\nm to 2673 m in the Ness Formation. Segregated FMT samples were taken at 2624.7\r\nm (both contained oil and gas), 2629 m (oil and gas), 2642 m (oil and gas), and\r\nat 2670 m (water with gas). The results from 34/10-37 indicated a more complex\r\nfault pattern at the crest of the structure than expected and it was decided to\r\ndrill a side track. The well bore was plugged back to 2055 m on 22 February\r\n1995 and abandoned as an oil discovery.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was performed\u003c/p\u003e\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"895","properties":{"OBJECTID":895,"wlbNpdidWellbore":2434,"wlbName":"6407/8-2","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThe main objective\r\nof drilling well 6407/8-2 was to establish the presence, quality and fluid\r\ncontent of the Jurassic Åre Formation sandstones in the Tau prospect, about 9\r\nkm west of the Draugen Field. The underlying Triassic grey/red beds provided a\r\nsecondary target.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eExploration well\r\n6407/8-2 was spudded with the semi-submersible installation "Dyvi\r\nStena" on 19 October 1994 and drilled to TD at 1950 m in the Triassic Grey\r\nBeds. The well was drilled with seawater and hi-vis pills down to 1140 m, with\r\nKCl polymer mud from 1140 m to 1733 m, and with a sized salt solids-free system\r\nfrom 1733 m to TD in the final 6" open hole. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe top of the Tau\r\nprospect\u00A0 reservoir section came in at\r\n1733 m and the well confirmed oil and gas charge in the prospect. The reservoir\r\nquality in the Åre Formation was better than expected at this location. The\r\nhydrocarbon column encountered was close to the predicted minimum success case\r\nmodel. The drilling location was well chosen in revealing the extent of the\r\ndifferent hydrocarbon phases in the structure. Further down-dip the gas cap\r\ncould have been missed. The proportion of gas to oil, however, currently\r\nrenders the discovery sub-commercial.\u003c/p\u003e\r\n\r\n\u003cp\u003eDiscrepancies\r\nbetween actual and prognosed depths are interpreted as reflecting uncertainty\r\nin the velocity field. The failure of the larger success outcomes is attributed\r\nto trap failure, either through fault-seal failure or breaching by thief Ile\r\nsands in the hanging wall.\u00A0 It is clear\r\nthat for this small- scale accumulation, distinguishing hydrocarbon phases is\r\nbelow seismic resolution.\u00A0 However, with\r\nwireline logs to calibrate seismic signature through gas, oil and water bearing\r\nreservoir sections the database for exploring adjacent prospects is excellent. \u003c/p\u003e\r\n\r\n\u003cp\u003eThree cores were cut\r\nin the 6" section from 1736 m to 1773 m in the Åre Formation. Core # 1 was\r\ncut from 1736 m -1744.8 m before jammin","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"896","properties":{"OBJECTID":896,"wlbNpdidWellbore":2444,"wlbName":"6406/2-1","wlbHistory":"\u003cb\u003e\r\nGeneral\r\n\u003c/b\u003e\r\n\u003cp\u003e\r\nExploration well 6406/2-1 was drilled on the B-prospect east in the block 6406/2, south of the Smørbukk Field and west of the Trestakk Field on Haltenbanken. The main purpose was to test the B-prospect sandstones of Middle to Early Jurassic age and the presence of hydrocarbons. Further, the reservoir quality at great depth (prognosed TD 5200 m) was to be tested. The main reservoir zones were prognosed to be the Ile and Tilje Formations, both prognosed to consist of mica-bearing sandstones with thin shale layers. The Garn and Tofte Formations, expected to be purer quartz-sandstones and more susceptible to diagenetic quartz cementation, were considered as additional potential.\r\n\u003cbr\u003e\r\nPossible sandstones were also prognosed at three different levels within the Cromer Knoll Group (in the Lysing and Lange Formations, of Turonian and Cenomanian age), and the well 6406/2-1 was aimed to test these levels within structural closure.\r\n\u003c/p\u003e\r\n\u003cb\u003e\r\nOperations and results\r\n\u003c/b\u003e\r\n\u003cp\u003e\r\nWell 6406/2-1 was spudded on 31 October 1994 with the semi-submersible \"Ross Rig\" . Due to environmental restrictions in the area, the drilling operations was stopped on 1 April 1995, and the well was temporarily plugged and abandoned on 9 April 1995 at a preliminary TD of 5295 m. Total non-productive time (NPT) for the well was 49,3 days. The reasons for lost time were mainly:\r\n\u003cbr\u003e\r\n- Core barrel stuck when attempting to pull out of hole with core no. 7 \u003cbr\u003e\r\n- Leakages on hose between yellow pod and shuttle valve for MPR \u003cbr\u003e\r\n- Stuck with 2 radioactive logging tools \u003cbr\u003e\r\n- Unsuccessful attempts to log with RCI / FMT tools\u003cbr\u003e\r\n\u003cbr\u003e\r\nThe well 6406/2-1 R was reentered 21 August 1995 and reached TD 20 September at 5892 m (5790 mTVD). The production testing of seven Jurassic reservoir levels was started 28 September 1995, and was completed 1 January 1996. The planned TD for the reentry was changed during drilling to 5800 m or 100 m below the Intra Åre Coal Sequence, in order to investigate the reservoir potential of the un","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"897","properties":{"OBJECTID":897,"wlbNpdidWellbore":2445,"wlbName":"6506/12-10","wlbHistory":"\u003cb\u003e\r\nGeneral\r\n\u003c/b\u003e\r\n\u003cp\u003e\r\nThe main objective for well 6506/12-10 was to appraise the down flanks hydrocarbons in the Garn, Ile, Tilje, and the Åre Formations, on the Smørbukk Field.\r\n\u003c/p\u003e\r\n\u003cb\u003e\r\nOperations and results\r\n\u003c/b\u003e\r\n\u003cp\u003e\r\nThe vertical appraisal well 6506/12-10 was spudded with the semi-submersible installation \"Ross Rig\" on 21 April and drilled to 5097 m in the Early Jurassic Åre Formation within the planned budget. Boulders were encountered drilling the 36\" section, and was the main reason why the 22\" underreamer became stuck in 20\" casing. As 12 1/4\" pilot hole was drilled to 890 m, gas flow occurred when flow checking with seawater at 628 m. The 20\" casing had to be set above this zone, which was considerable higher than planned. A 16\" liner was then set to obtain enough integrity below 16\" liner shoe to drill 17 1/2\" section to 2795 m for optimum setting depth of 13 3/8\" casing (lower part of Shetland). All other casing strings were set at planned depths according to \"Base case\" in the drilling programme. The well was drilled with seawater/bentonite down to 562 m, seawater/bentonite/CMC from 562 m to 1602 m, and Anco 2000 mud with Anco 208 glycol additive from 1602 m to 2790 m. Oil based mud (ANCO VERT) was used from 2790\r\nThe 6506/12-10 well proved no producible oil or gas in neither the Fangst nor the Båt Groups, thereby delineating hydrocarbons to the central areas of the field. The results of the 6506/12-10 well lead to the conclusion that there had to be drilled a sidetrack well in order to fulfill the obligations of the well and perform an extended production test of the Tilje Formation. Fourteen cores were cut in the Fangst and Båt Groups. FMT fluid samples were taken at four levels within the Åre and Tilje Formations. They contained mainly base oil (from the drilling fluid) and water. No indigenous hydrocarbons were found. It was decided to sidetrack the well and to penetrate higher up on the structure (6506/12-10 A). The vertical well was plugged with top plug (kick-off plug) in 13 3/8\" casing ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"898","properties":{"OBJECTID":898,"wlbNpdidWellbore":2454,"wlbName":"33/9-18","wlbHistory":"\u003cb\u003eGeneral\u003c/b\u003e\r\n\r\n\u003cp\u003eWell 33/9-18 was drilled to a\r\nstructure situated east of the Statfjord Field and south-west of the Tordis\r\nField. The main objective of the vertical well 33/9-18 was to explore the\r\nhydrocarbon potential of possible sandstones and to test the current geological\r\nmodel. The secondary objective was to explore the hydrocarbon potential of a\r\nlead in the Heather Formation. \u003c/p\u003e\r\n\r\n\u003cb\u003eOperations and results\u003c/b\u003e\r\n\r\n\u003cp\u003eExploration well 33/9-18 was spudded on 16\r\nNovember 1994 with the semi-submersible installation Deepsea Bergen and drilled\r\nto TD at 3253 m in the Late Jurassic Draupne Formation. The 36" and\r\n26" hole sections were swept with high viscosity bentonite pills. The 17\r\n1/2" and the 12 1/4" hole sections were drilled with KCl/PAC POLYMER\r\nand KCl mud system to prevent bit balling. No shallow gas was recorded.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well 33/9-18 had tight spots from\r\n325 m to TD. Experienced differential sticking at 1230 m, 1650 m, 1680 m and\r\ntight hole from 1652 m to 3140 m. Bit balling occurred in 26" and 12\r\n1/4" section. High viscosity bentonite pills were pumped to improve the\r\nflow pattern in an attempt to minimize balling problems. \u003c/p\u003e\r\n\r\n\u003cp\u003eFrom 2450 m and down to base Cretaceous at\r\n2849 m the pore pressure increases and reaches approximately 1.54 g/cc which is\r\nthe maximum pore pressure in the well. The rest of the well has been\r\ninterpreted as being drilled into the Viking Group, which here contain large\r\nslump/slide blocks of Statfjord Formation, Dunlin Group and Brent Group. Within\r\nthose blocks, the pore pressure seem to be somewhat higher than original\r\npressures in the Statfjord Field. FMT pressures gives pressures in the range of\r\n1.47 g/cc at 3006 m and 1,5 g/cc at 3019 m. No fluid samples were collected in\r\nthe well.\u003c/p\u003e\r\n\r\n\u003cp\u003eTwo cores were cut in Draupne Formation\r\n(core no. 1 was cut in the interval 2967-2978 m and core no. 2 was cut in\r\ninterval 3045-3054 m) and 1 core in Heather Formation (in the interval\r\n3233-3242 m). No hydrocarbon shows ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"899","properties":{"OBJECTID":899,"wlbNpdidWellbore":2455,"wlbName":"33/9-18 A","wlbHistory":"\u003cb\u003eGeneral\u003c/b\u003e\r\n\r\n\u003cp\u003eWell 33/9-18 A was drilled to a structure\r\nsituated east of the Statfjord Field and south-west of the Tordis Field. The\r\nmain objective of well 33/9-18 A was to test the lithology of a strong seismic\r\namplitude within the same prospect as drilled in well 33/9-18. Well 33/9-18 A\r\nis a sidetrack from well 33/9-18.\u003c/p\u003e\r\n\r\n\u003cb\u003eOperations and results\u003c/b\u003e\r\n\r\n\u003cp\u003eExploration well 33/9-18 A was spudded on\r\n21 December 1994 with the semi-submersible installation Deepsea Bergen and\r\ndrilled from kick-off at 1974 m to TD at 3597 m in the Late Jurassic Draupne\r\nFormation. The 12 1/4" hole section was drilled with KC1/PAC POLYMER and\r\nKCl mud system to prevent bit balling. No shallow gas was recorded.\u003c/p\u003e\r\n\r\n\u003cp\u003eParts of the 12 1/4" section have\r\nanomalous resistivity data. The MWD data records from 3070 m to TD are missing,\r\ndue to washout, lost signal, stuck pipe and MWD tool lost in hole. No wireline\r\nlogging was performed. 1 core was cut in the Draupne Formation the interval\r\n3397-3404.5 m. No fluid samples were collected. Bit balling was observed\r\nseveral times and a lot of pills were pumped to prevent balling, but minor\r\neffects were observed. Dyno-CC-115 (soap) pills showed best results. Drilling\r\nfrom 3145 m to 3397 m had to stop after 49 m due to bad weather. Drilling\r\ncontinued after 7 days stop and the flow rate was increased to maintain a\r\npressure of 280 bar. At TD the actual pressure was nearly 100 bar less than the\r\n"theoretical" pressure. This pressure drop was caused by wash out\r\nbetween two drill collars. Got differential stuck at 3512 m when pulling out of\r\nthe hole. Cut the string at 3382 m to get free. Extra cost related to logistics\r\nis estimated to approximately 3.3 mill. NOK. The well was plugged and abandoned\r\nafter being stuck for 83.5 hrs.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well has been interpreted to penetrate\r\nlarge slump/slide blocks consisting of the Brent Group, the Dunlin Group and\r\nthe Statfjord Formation which are deposited within the Draupne Formation. The\r\nstrong seismic ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"900","properties":{"OBJECTID":900,"wlbNpdidWellbore":2460,"wlbName":"34/7-24 S","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell is located east of the Statfjord Øst\r\nfield and west of the Vigdis and Tordis Fields in the Tampen area in the Northern North Sea. The main objective of the well was to prove presence of sandstone and\r\nhydrocarbons in the Draupne Formation. The wells earlier drilled in the H-Area,\r\n34/7-21, -21 A in H-Sentral and -23 S and -23A in H-Vest, proved oil bearing Late\r\nJurassic Intra Draupne Formation sand. The discoveries in H-Sentral and H-Vest\r\nwere however not in direct pressure communication. Well 34/7-24 S was drilled\r\nin a structural low compared to the other wells in the area and was mainly\r\ndesigned to test the continuity of the discovery made in H-Vest 34/7-23\r\nS&A. The 34/7-24 S well was prognosed to penetrate top reservoir 63 m below\r\nthe deepest penetrated ODT in the area. No OWC had been proved in the H-Area\r\nand the 34/7-24 S well was placed structurally relatively deep in order to\r\npossible reach an OWC in case of a sand bearing top Draupne interval. \u003c/p\u003e\r\n\r\n\u003cp\u003eSecondary objectives of the well were\r\npossible gravity deposited sandstones within the Middle and Lower Draupne\r\nSequences\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 34/7-24 S was spudded with the semi-submersible\r\ninstallation Vildkat Explorer on 25 February 1995 and drilled to TD at 3145 m (2938 m TVD) 54 m TVD into Late Jurassic sediments of the Heather Formation.\r\nDue to the nearness to the Snorre-Statfjord pipeline at the target position the\r\nwell had to be drilled deviated. The distance between the spud and the target\r\nposition at Base Cretaceous level was approximately 900 m. The inclination was\r\nbuilt from vertical to 28 deg through the 12 1/4" section from 335 m to\r\n1296 m. Operations went without significant problems. The well was drilled with\r\nspud mud down to 1296 m, and with a pseudo-oil based mud system (NOVAMUL) from\r\n1296 m to TD. There was interpreted possible shallow gas from the MWD logs\r\nbetween 361 to 365 m. The zone did not show anything on the ROV or at the flow\r\ncheck.","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"901","properties":{"OBJECTID":901,"wlbNpdidWellbore":2476,"wlbName":"25/9-1","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 25/9-1 is\r\nlocated East of the Jotun area and Southwest of the small 25/6-1 Discovery.\r\nWell 25/9-1 was drilled to test the hydrocarbon potential of Middle Jurassic\r\nHugin Formation sandstones (Rummel prospect) with sandstones of the Lower\r\nPalaeocene Ty Formation as a secondary target.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 25/9-1\r\nwas spudded with the semi-submersible "Vildkat Explorer" 28 March\r\n1995 and drilled to a total depth of 2525 m as prognosed, 110.5 m into\r\nsediments of the Late Triassic Smith Bank Formation. The well was drilled with\r\nbentonite / sea water down to 1056 m and with "Anco 2000" mud with ca\r\n3% "Anco 208" glycols from 1056 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eNo shallow gas or\r\nboulder beds were encountered in the uppermost well section. The well penetrated\r\nmainly clays and claystones in the Nordland, Hordaland and Rogaland groups. A\r\nclean Quaternary sandstone was seen between 275 and 319 m. The Utsira (754.5 m\r\n- 1000 m) and Skade (1284.5 m -1344.5 m) Formation sandstones were also\r\npresent. Top Våle Formation was reached at 2030.5 m but no Ty Formation sands\r\nwere present and the lithology consisted mainly of limestones and chalk, which\r\ncontinued down to top Shetland Group at 2043.5 m. The Shetland Group consisted\r\nmainly of chalk with the Cromer Knoll Group consisting of limestones\r\ninterbedded with clay stones and marls. The Hugin Formation sandstones came in\r\nas prognosed at 2184.5 m and were found to be water bearing. One 11.5 metre\r\ncore was cut. The core showed excellent reservoir parameters. \u003c/p\u003e\r\n\r\n\u003cp\u003eNo hydrocarbons were\r\nfound in the Våle Formation. Weak shows were seen in drilled cuttings from two\r\nintervals; the Lista Formation from 1951 m to 2017 m and in the Draupne and\r\nHeather formations from 2167 to 2184.5 m and in a number of sidewall cores\r\nrecovered from wire line log run 2F, interval 1988 m to 2413 m. Post well\r\norganic geochemical analysis confirmed traces of migrated hydrocarbons present\r\nin ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"902","properties":{"OBJECTID":902,"wlbNpdidWellbore":2505,"wlbName":"1/3-7","wlbHistory":"\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 1/3-7 is located on the Hidra High\r\nin the North Sea. It was drilled to appraise the 1/3-6 Oselvar condensate\r\ndiscovery made in Paleocene Forties Formation sandstones. The well was placed\r\ndown-flanks on the structure relative to the discovery well in order to\r\npenetrate the hydrocarbon-water contact and further appraise reservoir\r\nproperties and production rates. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 1/3-7 was spudded with the\r\n3 leg jack-up installation West Epsilon on 13 February 1995 and drilled to TD\r\nat 3345 m in the Paleocene Våle Formation. A gas kick was taken at 1740 m in\r\nthe top of the Hordaland Group, later it was found that the gas probably\r\noriginated from a limestone less than one meter thick. The hole packed off, the\r\nstring had to be cut off at 1564 m, and the hole was plugged back. A technical\r\nsidetrack (1/3-7 T2) was made from 1204 m. This sidetrack failed as the bit\r\nfell back into the original hole during a wiper trip. A new and successful\r\ntechnical sidetrack (1/3-7 T3) was made from 1202 m. A second gas kick occurred\r\nin the T3 sidetrack when reaching 1741 m. This kick was controlled by the driller's\r\nmethod without significant problems or extra rig time. The extra activity\r\ncaused by the first kick prolonged the rig time with 23 days. Due to poor hole\r\nconditions no open hole logging was performed in the 12 1/4" section. As\r\nthe West Epsilon was available only up to 28 May open hole logging at final TD\r\nwas also abandoned in order to secure time for the well test. The reservoir was\r\nlogged through casing. The well was drilled with sea water down to 207 m and\r\nwith gelled mud from 207 m to 1204 m. From 3103 m to TD it was drilled with a\r\nsalt polymer.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eTop Forties Formation was encountered at\r\n3175 m. The Forties","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"903","properties":{"OBJECTID":903,"wlbNpdidWellbore":2517,"wlbName":"34/10-38 S","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 34/10-38 S was drilled to appraise\r\nthe 34/10-17 Rimfaks Discovery south-west of the Gullfaks field in the North\r\nSea. The primary objective was to test the hydrocarbon potential of the Middle\r\nJurassic Brent Group in Segment 1 of the structure. Secondary objective was to\r\ntest the hydrocarbon potential of the Early Jurassic Statfjord Group in Segment\r\n2.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 34/10-38 S was spudded\r\nwith the semi-submersible installation Deepsea Bergen on 5 April 1995 and\r\ndrilled to TD at 3940 m (3393 m TVD) in the Late Triassic Lunde Formation. Drilling\r\nwent forth without significant problem. Lost time was mostly related to logging\r\nproblems in the 8 1/2" section. The well was drilled with bentonite and\r\nCMC/EHV down to 670 m, with ANCO 2000 mud from 670 m to 2075 m and with oil\r\nbased Safemul PE/SE mud from 2075 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe results of the well differed from the\r\ngeological prognosis. The Viking Group and most of the Brent Group in segment 2\r\nwas eroded and the remaining of the Brent Group was heavily faulted and\r\nfractured. Top Brent Group came in at 3021 m (2653.8 m TVD). Top Statfjord Group\r\nwas penetrated at 3451 m (2995.2 m TVD), about 200 m shallower than prognosed.\r\nThe Brent Group, the Cook Formation and the Statfjord Group proved to be\r\nhydrocarbon bearing. Pressure samples and log analysis proved an oil-water\r\ncontact at 3585.6 m (3103.5 m TVD) in the Statfjord Group. Shows and log\r\nanalysis indicated, however, oil with low saturation down to approx, 3658 m.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNine cores were cut in the well. The\r\nfirst core was cut from 3140 to 3159 m but recovered only a 10 cm piece. Cores\r\n2 to 9 were cut in the Statfjord Group from 3465 m to 3631 m with generally\r\ngood ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"904","properties":{"OBJECTID":904,"wlbNpdidWellbore":2530,"wlbName":"34/10-37 A","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 34/10-37 was drilled in the Tampen\r\nSpur area, ca 8 km WNW of the Gullfaks Sør Field. The results from 34/10-37\r\nindicated a more complex fault pattern at the crest of the structure than\r\nexpected and it was decided to drill a sidetrack.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe objective of the sidetrack, 34/10 -\r\n37 A, was to investigate the presence of a low angle fault at the crest of the\r\nD-prospect, which could explain the missing sections of the Tarbert Formation\r\nin 34/10-37. The well was planned to penetrate the top of the Brent Group at a\r\nhigher level than in 34/10-37 and terminate 50 m TVD below the oil-water\r\ncontact in the Brent Group.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eAppraisal well 34/10 - 37 A was kicked\r\noff through casing at 2049 m in well 34/10-37 on 22 February 1995 using the\r\nsemi-submersible installation Deepsea Bergen. It was drilled to TD at 2950 m in\r\nthe Middle Jurassic Ness Formation. No significant problems were reported from\r\nthe operations. The well was drilled with KCl/PAC mud from kick-off to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eIn addition to the formations encountered\r\nin 34/10-37 the well encountered the Rødby Formation, the Mime Formation and\r\nthe Draupne Formation. Well 34/10-37 A penetrated the top of the Brent Group 15\r\nm deeper than prognosed, but higher than in 34/10-37. An almost complete\r\nsequence of the Tarbert Formation was found in this well. The Brent Group\r\nproved to be hydrocarbon bearing with an "oil down to" at 2622 m TVD\r\nMSL. \u003c/p\u003e\r\n\r\n\u003cp\u003eFour conventional core were cut from 2664\r\nm to 2741 m in the Tarbert and Ness Formations. No FMT samples were collected\r\nin the well.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was suspended on 3 April 1995 as\r\nan oil appraisal\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was tested over the interval\r\n2667 to 2697 m, and flowed with a rate of 1950 Sm3/day oil and 645000 Sm3/day\r\ngas (GOR = 330 Sm3/Sm3). The bottom hole temperature measured during the test\r\nwas 97.2 deg C. A total of 4235 Sm3 oil was transferred to the vessel Crystal Sea an","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"905","properties":{"OBJECTID":905,"wlbNpdidWellbore":2552,"wlbName":"30/9-18","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 30/9-18 is located on the Bjørgvin\r\nArch south of the Oseberg Sør Field and North of the 30/9-16 K Oseberg Sør\r\nDiscovery. This is in the Northern North Sea. The well was drilled to clarify\r\nthe Oseberg Sør development strategy. The primary objective was to establish\r\nthe extent of the high-permeability Tarbert reservoir found in well 30/9-16.\r\nSecondary objectives were to test the lower Brent Group, the Cook Formation,\r\nand the Statfjord Formation. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 30/9-18 was spudded with the semi-submersible\r\ninstallation Treasure Saga on 14 March 1995 and drilled to TD at 2994 m in the\r\nLate Jurassic Drake Formation. The 24" hole was drilled from 193 m MD to\r\n557 m MD. Shallow gas was predicted at 590 m MD. The 18 5/8" casing was\r\nset at 547 m MD. As the cement was displaced bubbles from the hole was observed\r\nindicating shallow gas. Displaced out the entire cement volume and filled the\r\nannulus with 1.3 sg mud. Mixed and pumped gas block cement around. The well was\r\ndrilled with spud mud down to 557 m and with KCl/polymer mud from 557 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eFormation tops in the Tertiary and\r\nJurassic sections came in slightly higher than prognosed. However, they were\r\nwithin the prognosed uncertainty range. The well penetrated the Brent Group\r\nreservoir zones and they were water bearing. Very weak oil shows were reported in\r\nthe interval 2640 to 2780 m in the Heather/Tarbert intervals during drilling.\r\nIntra Heather Sandstone and Tarbert Formation combined contained 127 m gross\r\nsand (67.5 m net). The Ness Formation was 195 m thick with 54.5 m net sand. The\r\nCook and Statfjord Formations were not drilled. RFT formation pressures gave\r\nthree distinct and separate water gradients, one covering the Intra Heather sandstone/Tarbert\r\nFormation and two separate gradients covering the Ness Fm. The three water\r\ngradients indicated that there was possibly no pressure communication between\r\nthe three zones. No cores were cut and no wire line","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"906","properties":{"OBJECTID":906,"wlbNpdidWellbore":2562,"wlbName":"25/11-19 S","wlbHistory":" \u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n \r\n \u003cp\u003eWell 25/11-19 S was\r\n drilled on Licence 001, awarded in the first licence round in 1965. It was the\r\n last appraisal well on the Balder Field before it was decided to go ahead with\r\n Plan for Development in 1995. The well was located to penetrate the top\r\n reservoir of " Balder Mound 6" in a well-defined structurally high\r\n position. The primary target was a massive sand in the Hermod Formation; the\r\n secondary target was the Eocene Balder Formation Sand. The general objective of\r\n well 25/11-19 S was to reduce the range of uncertainty associated with the\r\n reserve basis for Balder Mound 6. The well was drilled as a directional well\r\n for potential re-entry as a future horizontal producer. \u003c/p\u003e\r\n \r\n \u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n \r\n \u003cp\u003eAppraisal well\r\n 25/11-19 S was spudded with the semi-submersible installation "Vildkat\r\n Explorer" on 24 April 1995 and drilled to TD at 2250 m (2019 m TVD SS) in\r\n Triassic (Late Rhaetian) sediments of the Statfjord Formation. The well was\r\n drilled with seawater spud mud down to 1015 m and with oil based "Safemul"\r\n mud from 1015 m to TD. Shallow gas was neither prognosed nor observed. The well\r\n was drilled vertically down to 1032 m before starting to build angle and at top\r\n of the primary target, the Hermod sand, the deviation was 38.2 deg. \r\n . An 8 1/2" inch hole was drilled to an intermediate depth of\r\n 2096 m where an extensive wire line logging program was performed. Then an 8\r\n 1/2" hole was drilled to TD of 2250 m and final logging was performed. The\r\n 25/11-19 S confirmed oil in the Hermod sand. A good oil water contact was\r\n defined by wire line logs, extensive MDT sampling and pressures at 1922.5 m\r\n (1760.5 m TVD SS) in the Hermod reservoir sand. Furthermore, gas reserves were\r\n proved in the secondary target, the Balder Formation sand, and pressure data\r\n indicated a potential GOC at 1839.2 m (1694.8 m TVD SS). Three cores were cut\r\n in the Sele and Hermod Formations from 1871 to 1937 ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"907","properties":{"OBJECTID":907,"wlbNpdidWellbore":2569,"wlbName":"30/9-17 R","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 30/9-17 R is a re-entry of well 30/9-17,\r\nwhich was terminated due to gas and mud flow from the annulus behind 9\r\n5/8" casing. The re-entry was made after the rig, Treasure Saga, had\r\ncompleted drilling the replacement well 30/9-18 ca 50 m to the east-southeast\r\nof the 30/9-17 location. The purpose of the re-entry was plugging and permanent\r\nabandonment.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 30/9-17 was re-entered (30/9-17 R) with the semi-submersible\r\ninstallation Treasure Saga on 11 April 1995. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was plugged and permanently\r\nabandoned on 13 April 1995 and classified as a junk well.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was performed.\u003c/p\u003e\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"908","properties":{"OBJECTID":908,"wlbNpdidWellbore":2573,"wlbName":"25/8-6","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 25/8-6 was\r\ndrilled to appraise the 25/8-5 S Discovery (Jotun) resource base and to confirm\r\nthe OWC. The well is located close to the crest of the field, close to the\r\nwestern block boundary and PL103, who participated in the well.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was drilled\r\nas a possible future vertical sub-sea producer. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eAppraisal well\r\n25/8-6 was spudded with the semi-submersible installation "Vildkat\r\nExplorer" on 19 May 1995 and drilled to TD at 2565 m. The well was drilled\r\nwith seawater and hi-vis pills down to 1060 m and KCl/glycol mud from 1060 m to\r\nTD. Due to bad hole condition it was impossible to get wire line logs below\r\n1460 m. The well was plugged back on 6 June and technically sidetracked& (25/8-6T2) from just below the 13 3/8" casing\r\nat 1073 m using "Lo-Tox" mineral oil based mud. This well bore built\r\nup to 13& at 1329 m and then dropped back to vertical at 1600 m, the well was\r\nkept vertical down through the reservoir. It was drilled to TD at 2577 m in the\r\nin the Early Paleocene Ekofisk Formation. Successful wire line logging was\r\nachieved in this well bore. The well confirmed oil in the Heimdal Formation\r\nwith OWC at 2090 m TVD SS (2122.6 m RKB in the technical sidetrack) in clean\r\nsand.\u003c/p\u003e\r\n\r\n\u003cp\u003eEight cores were cut\r\nin the first well bore. Two were cut in shales of the Lista Formation (2054m to\r\n2057 m and 2057 m to 2065 m). Due to very slow coring rate, coring was\r\ndiscontinued and a 12 1/4" hole was drilled down to 2077 m at the next\r\ncore point. Six cores were subsequently cut in Heimdal Formation sandstone in\r\nthe interval 2077 m to 2137.5 m. MDT fluid samples were taken in the Heimdal\r\nFormation at 2082.2 m (oil), 2122.1 m (oil), 2123.0 m (water + ca 15% oil),\r\n2143.5 m (water), and 2145 m (water). After running TD logs, a string of 10-3/4"\r\nx 9-5/8" production casing was run and cemented, and the well was\r\nsuspended on 27 June 1995 as an oil appraisal and potential future","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"909","properties":{"OBJECTID":909,"wlbNpdidWellbore":2574,"wlbName":"34/10-39 S","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 34/10-39 S was drilled on mid-way\r\nbetween the Gullfaks and Statfjord Fields on Tampen Spur in the North Sea.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat ell 34/10-39 S was spudded with\r\nthe semi-submersible installation Deepsea Bergen on 31 May 1995 and drilled to\r\nTD at 3290 m (3142 m TVD) in the Early Jurassic Statfjord Group. No significant\r\nproblem was encountered in the operations. The well was drilled with seawater\r\nand hi-vis pills down to 476 m, with KCl/polymer mud from 476 m to 2060 m, and\r\nwith ANCO 2000 mud from 2060 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe Viking Group was encountered at 2482\r\nm (2448 m TVD) and consisted of 22 m TVD of excellent source rock Draupne\r\nFormation and 55 m TVD of Heather Formation. The top of the Brent Group was\r\npenetrated at 2562 m (2525 m TVD), approximately 50 m lower than prognosed and\r\nproved to be water bearing. The Cook Formation was also water bearing. The well\r\nwas extended to the Statfjord Group, which also proved to be water bearing. Weak\r\noil shows were recorded in some siltstones in the interval 2310 m to 2400 m in\r\nthe Shetland Group, otherwise no signs of hydrocarbons were observed in the\r\nwell.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo cores were cut. Very good FMT pressure\r\npoints were acquired, but no fluid sample was taken.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was permanently abandoned on 20\r\nJune 1995 as a dry well.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eTesting\u003c/span\u003e\u003c/b\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo drill stem test was performed. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"910","properties":{"OBJECTID":910,"wlbNpdidWellbore":2576,"wlbName":"17/3-1","wlbHistory":"\u003cb\u003e\r\nGeneral\r\n\u003c/b\u003e\r\n\u003cp\u003e\r\nBlock 17/3 is situated approximately in the center of a broad, elongated Triassic rift basin composed of the Stord and Egersund basins. The well is located on a well-defined horst structure (Bark Prospect) in the northern part of the block, in an almost unexplored area in the southern part of the Stord Basin. Due to the \"wildcat\" nature of the well there were many unknowns and \"worst case scenarios\" had to be planned for. The well was designed for two objectives with different pressure regimes: The primary objective was the Late Jurassic Sandnes Formation at 1.20 sg.  The Permian Rotliegendes Group at 1.55 sg was a secondary objective. This necessitated an expensive deep 13 3/8\" casing (2312 m) to ensure that the 2 objectives could be properly evaluated and that the well could be completed in the 8 1/2\" section. The expected hydrocarbon phase was oil. The prognosed TD of the well was 3300 m RKB, 309 m below the supposed Top Rotliegendes. This was in order to reach the highly dipping markers of assumed Paleoz\r\n\u003c/p\u003e\r\n\u003cb\u003e\r\nOperations and results\r\n\u003c/b\u003e\r\n\u003cp\u003e\r\nWildcat well 17/3-1 was spudded with the semi-submersible installation \"Wildcat Explorer\" on 29 June 1995 and drilled to a total depth of 2852.15 m in metamorphic basement rock, dated 410 My. The well was drilled with seawater down to 949 m and with water based gypsum mud from 949 m to TD. The well came in under budget and almost 14 days ahead of schedule. A major contributing factor to the latter was the shallower than expected TD, 2852 m (basement) as opposed to 3300 m, due to the Permian section being non-existent. The primary objective Sandnes Formation was encountered at 2387 - 2409 m, about 50 m shallower than prognosed, with a hydrostatic pore pressure (1.05 sg emw from RFT and MDT) and only ~2 m of gas was found at the top of the reservoir. The Permian series were not present, as the Triassic Smith Bank Formation was directly deposited on metamorphic basement. The secondary objective, the Rotliegendes Group, was never encountered ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"911","properties":{"OBJECTID":911,"wlbNpdidWellbore":2578,"wlbName":"6608/10-5","wlbHistory":"\u003cb\u003e\r\nGeneral\r\n\u003c/b\u003e\r\n\u003cp\u003e\r\nThe main objective of well 6608/10-5 was to prove oil accumulation in Middle and Lower Jurassic Sandstones of the Fangst and Båt Groups.\r\n\u003c/p\u003e\r\n\u003cb\u003e\r\nOperations and results\r\n\u003c/b\u003e\r\n\u003cp\u003e\r\nWildcat well 6608/10-5 was spudded with the semi-submersible installation \"Ross Isle\" on 5 July 1995 and drilled to a total depth of 3200 m, in the Åre formation. The well was drilled with seawater and bentonite/CMC EHV to 1215 m and KCl/Anco 2000 mud with 3-5 % glycol (Anco 208) from 1215 m to TD. No hydrocarbons were found. No cores were cut. No wire line fluid samples were taken. The well was plugged and abandoned as a dry well on 6 August 1995.\r\n\u003c/p\u003e\r\n\u003cb\u003e\r\nTesting\r\n\u003c/b\u003e\r\n\u003cp\u003e \r\nNo drill stem test was performed\r\n\u003c/p\u003e\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"912","properties":{"OBJECTID":912,"wlbNpdidWellbore":2599,"wlbName":"9/2-5","wlbHistory":"\u003cb\u003e\r\nGeneral\r\n\u003c/b\u003e\r\n\u003cp\u003e\r\nThe objective for the well 9/2-5 was to appraise the extension of the oil-bearing sequence in the Beta East structure on the Yme field.\r\n\u003c/p\u003e\r\n\u003cb\u003e\r\nOperations and results\r\n\u003c/b\u003e\r\n\u003cp\u003e\r\nAppraisal well 9/2-5 was spudded with the semi-submersible installation \"DeepSea Bergen\" on 23 June 1995 and drilled to a total depth of 3355 m in the Middle Jurassic Bryne Formation. The well was drilled with very small target tolerances, hence a directional assembly with motor was utilized in order to steer. The well had a final inclination of 2.1° and hit target according to tolerances. The well was drilled 13 days faster than planned; especially the drilling operations went faster than expected. The well was planned and drilled without the use of 20\" casing, which gave substantial time saving. The well was drilled with seawater and hi-vis pills down to 1750 m and KCl mud with glycol from 1750 m to TD.\r\nThe Sandnes and the Bryne Formations were penetrated slightly deeper than prognosed. Both proved better reservoir quality than expected based on information from the well 9/2-3. FMT sampling proved that the Beta East structure has the same oil gradient and water gradient as the Gamma structure. The oil/water contact was recorded at 3270 m TVD (3247 m TVD MSL). Two cores were cut in the interval 3154 to 3193 m in the Sandnes Formation. Several FMT runs were initiated to obtain representative formation fluid samples from the Sandnes Formation. The content of the first segregated sample, Run 2A, confirmed considerable invasion of mud filtrate and made it necessary to increase the volume of the pre-flush chamber. This change in tool configuration led to several misruns due to operational tool failures. Finally, in Run 2F, indications of a successful segregated sample were obtained and the 4-liter PVT chamber was transferred to standard PVT bottles for onshore PVT analysis. One more attempt, Run 2G, was performed\r\n\u003c/p\u003e\r\n\u003cb\u003e\r\nTesting\r\n\u003c/b\u003e\r\n\u003cp\u003e \r\nNo drill stem test was performed\r\n\u003c/p\u003e\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"913","properties":{"OBJECTID":913,"wlbNpdidWellbore":2610,"wlbName":"6506/12-10 A","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThe main objective of well 6506/12-10 A\r\nwas to appraise the down flanks hydrocarbons in the Garn, Ile, Tilje, and the\r\nÅre Formation, on the Smørbukk Field. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThe appraisal sidetrack well 6506/12-10 A\r\nwas kicked off with the semi-submersible installation "Ross Rig" from\r\n2823 m in 6506/12-10 on 25 June 1995 and drilled to 6260 m with a total cost\r\nconsiderably higher than planned budget. The higher costs were mainly due to\r\nkick off and orienting problems from the vertical well, lots of trips to change\r\nbits, milling cones lost in the 12 1/4" hole and problems cementing the\r\n7" liner. In general the drilling rate was lower than expected. Oil based\r\nmud (ANCO VERT) was used trough out the sidetrack. High mud weight (1.80 g/cm3)\r\nwas used in the beginning to prevent formation damage during drilling. This can\r\nhave caused lower ROP than expected. Prior to testing, a lot of leakage\r\nproblems occurred within the test string mainly due to bad quality of the\r\no-rings in the Halliburton test-valves. The string was pulled and reran 5 times\r\nbefore all the problems were sorted out. Total lost times in the test phase was\r\n893 hrs (squeeze cementing of 7" liner, leak in BHA of the test string,\r\nBOP problems, WOW, fishing of packer slips). \u003c/p\u003e\r\n\r\n\u003cp\u003eEleven cores were cut in the Tilje and\r\nÅre Formations. Two FMT samples were taken in the Garn Formation (4397.7 m TVD\r\nand 4402.7 m TVD, respectively) and one in the Tilje Formation (4806.8 m TVD).\r\nThe Garn samples contained water while the Tilje sample contained oil. The\r\n6506/12-10A well proved producible oil in the Garn, Ile, Tilje and upper parts\r\nof the Åre Formations in good sand intervals. After testing the well 6506/12-10\r\nA was permanently plugged and abandoned on 11 December 1995 as an oil and gas\r\nappraisal well. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting \u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThe test plan included short tests of the\r\nÅre and Tilje Formations followed by a long term production period. Therea","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"914","properties":{"OBJECTID":914,"wlbNpdidWellbore":2612,"wlbName":"25/8-7","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eExploration Well\r\n25/8-7 is located East North-East of the Jotun Field. The two main objectives\r\nfor drilling well 25/8-7 were to test the hydrocarbon potentials of the\r\nsandstones in the Lower Palaeocene Heimdal Formation (Krap prospect) and in the\r\nMiddle Jurassic Hugin Formation.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 25/8-7 was\r\nspudded with the semi-submersible installation "Dyvi Stena" on 21\r\nJuly 1995 and drilled to a total depth of 2380 m, 40 metres into the Early\r\nJurassic Amundsen Formation. The well was drilled with seawater and high\r\nviscous pills through the 36" and 17 1/2" hole sections down to 1070\r\nm. After setting the 13 3/8" casing the mud system was changed to a 1.27\r\nSG KCL/ polymer system with 3 - 4 % glycol added for drilling the 12 1/4"\r\nand 8 1/2" sections to final TD. No shallow gas or boulder beds were\r\nencountered in the uppermost well section.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well penetrated\r\nmainly clays and claystones in the Nordland, Hordaland and Rogaland groups.\r\nGrid Formation sands were encountered from 1293 m to 1348 m and 1484 m to 1504\r\nm. Minor thin distal remnants of the Heimdal Formation sands were encountered\r\nbetween 2050 and 2061.5 metres, however these proved water wet. Top Ty\r\nFormation was reached at 2157 m, consisting of clean sandstone divided by a thin\r\nshale bed. It continued down to top Shetland Group at 2209 metres. No\r\nhydrocarbons were found in the Ty Formation. The Shetland Group consisted\r\nmainly of chalk with the Cromer Knoll Group consisting of limestones\r\ninterbedded with claystones and marls. The Hugin Formation sandstones came in\r\nat 2318 m and were found to be water bearing. Traces of dark brown tarry dead\r\noil staining together with weak, dull yellow fluorescence and slight\r\npetroliferous odour was seen in the Heimdal Formation sands and claystones from\r\n2050 m to 2061.5 m. Similarly traces of dark brown tarry dead oil stained\r\ngrains were described at the top of the Hugin Formation at 2318 ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"915","properties":{"OBJECTID":915,"wlbNpdidWellbore":2617,"wlbName":"31/4-10","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 31/4-10 was drilled to appraise the\r\nBrage Field on the Bjørgvin Arch in the North Sea. The main objective was to\r\nconfirm hydrocarbons in the Sognefjord Formation. The secondary objectives were\r\nto obtain information about reservoir properties and stratigraphic development\r\nof the Fensfjord and Krossfjord Formations.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 31/4-10 was spudded with\r\nthe semi-submersible installation West Vanguard on 14 November 1995 and drilled\r\nto TD at 2342 m in Middle Jurassic sediments in the Heather Formation. The well\r\nwas drilled and logged without significant problems. It was drilled with spud\r\nmud down to 1010 m and with KCl/polymer mud from 1010 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eA 21 m thick Draupne Formation was\r\npenetrated from 2004 m to 2025 m. The Sognefjord Formation was encountered at\r\n2025 m and a total of 4.7 m net pay was calculated in the interval between\r\n2038.0 m and 2044.9 m. The average oil saturation over this interval is\r\nestimated to 50.6 %. The average porosity is calculated to 23 %. MDT pressure\r\nmeasurements gave an oil-water contact at 2045 m. Low saturations of residual\r\nhydrocarbons are observed in intervals below the oil-water contact down to\r\nbottom Sognefjord Formation at 2097.5 m. No gas-oil contact could be determined\r\nfrom pressure measurements or logs because of the low permeability over this\r\ninterval. However, a gas-oil contact at 2034.5 m was inferred from hydrocarbon\r\nshows on the cores. The Fensfjord Formation was encountered at 2167.5 m and a\r\ntotal of 3.2 m net pay was calculated between 2167.5 m and 2171 m. MDT pressure\r\nmeasurements gave an oil-water contact at 2171 m. Low saturations of residual\r\nhydrocarbons are observed in intervals below the oil-water contact down to\r\nbottom Fensfjord Formation at 2","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"916","properties":{"OBJECTID":916,"wlbNpdidWellbore":2623,"wlbName":"25/7-3","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 25/7-3 was a\r\ndiscretionary exploration well approximately 3 km south-south west of well\r\n25/8-5 S which discovered oil in the Elli structure. Block 25/7 is situated in\r\nthe South Viking Graben on the western side of the Utsira High, a basement high\r\nthat tilts slightly towards the east. The South Viking Graben has an\r\nasymmetrical profile bounded in the west by the Brae/Crawford Fault Zone and\r\nthe Utsira High to the east. The Elli structure is located on a basement\r\nterrace stepping up to the Utsira High from the Graben area. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe primary\r\nobjective of well 25/7-3 was to prove commercial reserves in Elli South by\r\ntesting the hydrocarbon potential of the Paleocene Upper Heimdal Formation.\r\nSecondary objectives were to define fluid contacts within the Heimdal\r\nFormation, to provide sufficient data for development planning start-up, find a\r\npossible point of production should the results be positive, and to obtain a\r\ngood well tie to the top Cretaceous and top Balder seismic reflectors.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eExploration well\r\n25/7-3 was spudded with the semi-submersible installation "Deepsea\r\nBergen" on 27 July 1995 and drilled to TD at 2540 m in the Late Cretaceous\r\nTor Formation. The AFE estimated time for the well was 28.1 days dry hole plus\r\n10.5 days to DST. Actual estimated drilling time was 23.6 days, and testing was\r\n9.8 days. The well was drilled with bentonite spud mud down to 1186 m and with\r\n"ANCO 2000" mud with ANCO 208 glycol additive from 1186 m to TD. Top\r\nLista Formation came in at 2052 m, ca 20 shallower than prognosed. Top Heimdal\r\nFormation was found at 2094 m. The Heimdal Formation was hydrocarbon bearing\r\nwith an OWC at 2114.5 m.\u003c/p\u003e\r\n\r\n\u003cp\u003eTwo cores were cut\r\nin the Heimdal Formation, both with full recovery. The first core was cut\r\n2099-2110.6 m, and the second at 2111-2130.2 m. Shows were described in the\r\ncores down to a depth of 2117 m. A total of 20 FMT pressure tests were taken,\r\nwith 19 successf","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"917","properties":{"OBJECTID":917,"wlbNpdidWellbore":2632,"wlbName":"30/3-7 S","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 30/3-7 S was drilled on the\r\nVeslefrikk Field, which is located due north of the Oseberg East Field. The\r\nobjective of the well was to explore the hydrocarbon potential in the Brent\r\nGroup, Intra Dunlin Sand and the Statfjord Formation in the B-prospect, west of\r\nthe Veslefrikk horst.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 30/3-7 S was spudded from\r\nthe fixed surface installation Veslefrikk A on 21 September 1995 and drilled to\r\nTD at 5581 m in the Lunde Formation. The 24" hole section from 467 m\r\nto 1472 m was drilled with Sea water/PAC converted to KCl/polymer mud. The 17\r\n1/2" section from 1472 m to 2870 m was drilled with KCl/PAC/XANVIS mud,\r\nthe 12 1/4" and 8 1/2" sections from 2870 m to 5581 m was drilled\r\nwith Ancovert oil based mud.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well drilled into the top of the\r\nJurassic sequence earlier than expected, and hydrocarbon filled sandstones of\r\nunknown stratigraphy were penetrated almost 400 m higher than prognosed. The\r\nwell was plugged back and a technical sidetrack was drilled and parts of the\r\nhydrocarbon filled interval was cored. Electric logs, core data, sidewall cores\r\nand paleo-dating as well as studies of the dip of layering and mineralogy, all\r\nshow that the well penetrated several faults of varying throw. The stratigraphic\r\nintervals include both the Brent Group and the Statfjord Formation with several\r\nrepeated and missing sequences. It soon became evident that the well never\r\nreached out to the B-prospect, but instead penetrated hydrocarbon bearing\r\nsandstones in several small fault blocks in the outskirts of the main\r\nVeslefrikk structure. A total of nine cores were cut, covering the base 2 m of\r\nthe Heather Formation and ca 100 m of the faulted Brent sequence. RFT pressure\r\npoints were recorded in the first Brent sequence (Tarbert/Ness) and in the\r\nsecond Brent sequence (Oseberg), but no fluid samples were taken on wire line.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was completed on 12 December\r\n1995 as an oil/gas discover","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"918","properties":{"OBJECTID":918,"wlbNpdidWellbore":2634,"wlbName":"34/10-40 S","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 34/10-40 S was drilled on the\r\nGullfaks fault block on Tampen Spur in the North Sea. The primary objective was\r\nto prove hydrocarbons in the Brent Group in Segment 7, North of the main\r\nGullfaks Field. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell was spudded through slot 19 on the\r\nGullfaks B platform on 13 August 1995 and drilled deviated to TD at 5900 m\r\n2375.6 m TVD) in the Early Jurassic Drake Formation. The well was drilled with\r\nSeawater and PAC mud down to 1495 m and with ANCO 2000 mud from 1495 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe Brent Group was penetrated at 5336 m\r\n(2118 m TVD) and contained a 6.5 m TVD gas column with a gas-water contact at\r\n5358.5 m (2125 m TVD). The well also penetrated, unexpectedly, a ca 40 m thick\r\nHeather Formation on top of the Brent Group. RFT pressure measurements\r\nindicated pressure depletion in the Brent Group due to production from the\r\nGullfaks Field. The well was therefore completed as a water injector.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo cores were cut and no wire line fluid\r\nsamples were taken. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was completed on 13 October 1995\r\nas a minor gas discovery and converted to development well 34/10-B-35.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eTesting\u003c/span\u003e\u003c/b\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo drill stem test was performed. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"919","properties":{"OBJECTID":919,"wlbNpdidWellbore":2635,"wlbName":"15/5-5","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 15/5-5 is located in the Northern North Sea, ca 15 km north of the Sleipner Field. The primary objective of the well\r\nwas to prove commercial volumes of oil in a prospect in the Late Paleocene Heimdal\r\nFormation. The well location was chosen so as to test the prospect in a\r\nposition with as little up dip reserves as possible.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 15/5-5 was spudded with the\r\nsemi-submersible installation Treasure Saga on 31 August 1995 and drilled to TD at 2645 m in the Early Paleocene Ekofisk Formation. Boulders were experienced\r\nin the interval 155 -170 m MD and some time was spent to correct the\r\ninclination. Otherwise operations went without problems and the well was\r\ncompleted well within schedule. The well was drilled with spud mud down to 1000\r\nm and with KCl/polymer mud from 1000 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well penetrated water bearing Grid\r\nFormation sands from 1479 m to 1807 m. The Heimdal Formation was encountered at\r\n2154 m with 27.4 m of net pay hydrocarbon-bearing reservoir sand down to the\r\nOWC at 2187m. The average porosity was calculated to 30.6 % and the average\r\nhorizontal core permeability was 1.9 Darcy. The OWC was based on formation\r\npressure measurements (MDT) and logs. The average oil saturation over the\r\ninterval was estimated to 67.4 %. The MDT data indicated a Free Water Level at\r\n2189.2 m. Oil shows and low saturation of migrated hydrocarbons were observed\r\nin selected intervals below the OWC down to 2191 m. The Heimdal Formation from\r\ntop to 2191 was the only interval in the well that had reported oil shows. An\r\n82 m thick water bearing sandstones of the Ty Formation was encountered at 2501\r\nm.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe interval 2157 - 2200 m was cored in 3\r\ncores using equipment especially developed for soft sediment coring. The original\r\ncore depths are 4 m shallow relative to wire line log curves. The cores covered\r\nmost of the oil zone and extended into the water leg. MDT fluid samples were\r\ntaken at 2157.5 m (mud filtrate","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"920","properties":{"OBJECTID":920,"wlbNpdidWellbore":2636,"wlbName":"2/8-15","wlbHistory":"      \u003cb\u003e\r\n      General\r\n      \u003c/b\u003e\r\n      \u003cp\u003e\r\n      Well 2/8-15 was drilled to test the hydrocarbon potential of the \"Noekken\" prospect, a low stratigraphic Chalk structure northeast of Valhall, lying between the Mode and the Trud salt domes and the Balder nose to the north. The prospect area has been technically active, with reactivation of faults and movements of the salt (until late Tertiary). The main reservoir objective for the Nøkken prospect was within the Late Cretaceous Tor Formation, the main producing interval in the nearby Chalk fields. Secondary potential was identified within the Ekofisk Formation.\r\n      \u003c/p\u003e\r\n      \u003cb\u003e\r\n      Operations and results\r\n      \u003c/b\u003e\r\n      \u003cp\u003e\r\n      Exploration well 2/8-15 was spudded with the semi-submersible installation \"Vildkat Explorer\" on 27 November 1995. A technical sidetrack of the well became necessary when a core head twisted off at 3360.5 m. The well was sidetracked at 3183 m and the new well bore was labelled 2/8-15 T2. Well 2/8-15 T2 was drilled to TD at 3750 m in the Late Cretaceous Hod Formation. The well was drilled with seawater/spud mud down to 1099 m, with \"ANCO 2000\" / KCl / Glycol mud from 1099 m to 2300 m, and with oil based \"ANCO VERT\" mud from 2300 m to TD.\r\n      \u003c/p\u003e\r\n      \u003cp\u003e\r\n      Top chalk was penetrated at 3177 m. Many of the formation tops came in close to forecast and the three identified possible chalk reservoirs; i.e. the upper and lower Ekofisk leads and the Tor Formation were all found to contain fair to good porosity close to prognosis. Lack of hydrocarbons throughout the well was evident and the porous limestones were 100 % water wet. Pore pressures as determined from the MDT were exactly as prognosed. An MDT sample was attempted at 3407 m without success. A further attempt was made at 3314.5 m in order to get a quality formation water sample. About l litre of OBM distillate filtrate fraction was recovered. This was confirmed using chromatograph-fingerprinting analysis conducted by Geoquest Laboratories. However, virgin water","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"921","properties":{"OBJECTID":921,"wlbNpdidWellbore":2640,"wlbName":"6406/12-2","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 6406/12-2 is\r\nlocated approximately mid way between the Njord Field and the small 6406/11-1 S\r\noil discovery. The main objective of the well was to prove oil accumulation in\r\nUpper Jurassic Sandstones in the Lambda prospect.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eExploration well\r\n6406/12-2 was spudded with the semi-submersible installation "Deepsea\r\nBergen" on 1 September 1995 and drilled to a total depth of 4367 m in\r\nMiddle Jurassic Melke Formation sandstones. The well was drilled with Bentonite\r\n/ CMC EHV down to 917 m, with "ANCO 2000" mud from 917 m to 2316 m,\r\nand with oil based "ANCOVERT" from 2316 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eDrilling performance\r\nwas good down to 3731 m but very low penetration rate was experienced below\r\nthis level to TD due to very hard formation.\u003c/p\u003e\r\n\r\n\u003cp\u003eThree cores were\r\ncut, one in Spekk Formation (shale), one in Rogn Formation II and one in Melke\r\nFormation. One FMT run was performed in the Rogn and Melke sandstone sections.\r\nThe FMT log was run with sample chambers to collect a sample of the formation\r\nfluid if possible. All the pressure points showed tight formation. The well was\r\npermanently abandoned on 17 October 1995 as a dry well.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test\r\nwas performed.\u003c/p\u003e\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"922","properties":{"OBJECTID":922,"wlbNpdidWellbore":2642,"wlbName":"6406/2-1 R","wlbHistory":"\u003cb\u003e\r\nGeneral\r\n\u003c/b\u003e\r\n\u003cp\u003e\r\nExploration well 6406/2-1 was drilled on the B-prospect east in the block 6406/2, south of the Smørbukk Field and west of the Trestakk Field on Haltenbanken. The main purpose was to test the B-prospect sandstones of Middle to Early Jurassic age and the presence of hydrocarbons. Further, the reservoir quality at great depth (prognosed TD 5200 m) was to be tested. The main reservoir zones were prognosed to be the Ile and Tilje Formations, both prognosed to consist of mica-bearing sandstones with thin shale layers. The Garn and Tofte Formations, expected to be purer quartz-sandstones and more susceptible to diagenetic quartz cementation, were considered as additional potential.\r\n\u003cbr\u003e\r\nPossible sandstones were also prognosed at three different levels within the Cromer Knoll Group (in the Lysing and Lange Formations, of Turonian and Cenomanian age), and the well 6406/2-1 was aimed to test these levels within structural closure.\r\n\u003c/p\u003e\r\n\u003cb\u003e\r\nOperations and results\r\n\u003c/b\u003e\r\n\u003cp\u003e\r\nWell 6406/2-1 was spudded on 31 October 1994 with the semi-submersible \"Ross Rig\" . Due to environmental restrictions in the area, the drilling operations was stopped on 1 April 1995, and the well was temporarily plugged and abandoned on 9 April 1995 at a preliminary TD of 5295 m. Total non-productive time (NPT) for the well was 49,3 days. The reasons for lost time were mainly:\r\n\u003cbr\u003e\r\n- Core barrel stuck when attempting to pull out of hole with core no. 7 \u003cbr\u003e\r\n- Leakages on hose between yellow pod and shuttle valve for MPR \u003cbr\u003e\r\n- Stuck with 2 radioactive logging tools \u003cbr\u003e\r\n- Unsuccessful attempts to log with RCI / FMT tools\u003cbr\u003e\r\n\u003cbr\u003e\r\nThe well 6406/2-1 R was reentered 21 August 1995 and reached TD 20 September at 5892 m (5790 mTVD). The production testing of seven Jurassic reservoir levels was started 28 September 1995, and was completed 1 January 1996. The planned TD for the reentry was changed during drilling to 5800 m or 100 m below the Intra Åre Coal Sequence, in order to investigate the reservoir potential of the un","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"923","properties":{"OBJECTID":923,"wlbNpdidWellbore":2644,"wlbName":"6406/2-2","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 6406/2-2 was drilled on the B\r\nstructure (Lavrans discovery) in the eastern part of the block, south of an\r\neast-west trending cross fault. The discovery well 6406/2-1 had previously been\r\ndrilled on the northern segment of the B structure. The cross fault was\r\nsuspected to act as a pressure barrier between the two segments, causing\r\nvariation in fluid types. The main objective of well 6406/2-2 was to prove\r\nhydrocarbons and verify fluid contacts in the southern segment, which seemed to\r\ndiffer from the northern segment in both the nature and intensity of the\r\nseismic amplitudes. An additional objective was to investigate any differences\r\nin reservoir development between the two segments. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eAppraisal well 6406/2-2 was spudded 12\r\nDecember 1995 with the semi-submersible installation "Ross Rig" and\r\nTD was reached at 5367 m (5351 mTVD) 12 February 1996 in the Åre Formation. The\r\nwell was drilled water based with bentonite down to 1272 m, with KCl and glycol\r\n(ANCO 208) from 1272 to 2858 m, and with oil-based mud from 2858 m to TD. The\r\nformation tops were drilled in accordance with the prognosis, and the\r\nlithologies drilled were largely similar to those reported from 6406/2-1. The\r\nJurassic succession was encountered 5-100 m deeper than in well 6406/2-1, due\r\nto the lower structural position of well 6406/2-2. As in well 6406/2-1, well\r\n6406/2-2 proved the presence of thick reservoir sandstones in the Garn, Ile,\r\nTofte and Tilje Formations. In addition, an 8 m thick sand was drilled in the lower\r\npart of the Ror Formation. The reservoir quality showed large variations, with\r\ngenerally poor porosity in the Garn Formation, good porosity in parts of the\r\nIle Formation, generally good porosity in the Tofte Formation, and zones with\r\ngood porosity especially in the lower part of the Tilje Formation. Other parts\r\nof the Ile and Tilje Formations, as well as the sandstone beds in the upper\r\npart of the Åre Formation, were tight as a","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"924","properties":{"OBJECTID":924,"wlbNpdidWellbore":2645,"wlbName":"6608/10-3 R","wlbHistory":"\u003cb\u003e\r\nGeneral\r\n\u003c/b\u003e\r\n\u003cp\u003e\r\nThe main objective of well 6608/10-3 was to appraise oil accumulation in the Jurassic Fangst and Båt groups in the Northern Fault Block on the Norne field off shore Mid Norway. \r\n\u003c/p\u003e\r\n\u003cb\u003e\r\nOperations and results\r\n\u003c/b\u003e\r\n\u003cp\u003e\r\nAppraisal well 6608/10-3 was spudded by the semi-submersible installation \"Ross Rig\" on 7 January 1993 and drilled to a total depth of 2921 m, into rocks of Lower Jurassic age. The well was drilled water based. Seawater/bentonite spud mud was used down to 469 m, seawater/CMC EHV spud mud from 469 m to 874 m, and Gyp/PAC polymer mud from 874 m to TD.\r\nOil and gas was encountered in the Early to Middle Jurassic Båt and Fangst Groups. Eleven cores were cut in the interval 2560 m to 2765 m, from the lower part of the Melke Formation, through the Fangst Group and into the Tilje Formation of the Båt Group. Four segregated FMT samples were taken at 2599.2 m in the Garn Formation (gas, mud filtrate, and small amount of oil), 2603.2 m in the Garn Formation (mud filtrate, gas, and oil), 2624.5 m in the Ile Formation (gas, and oil), and at 2715.2 in the Tilje Formation (mud filtrate and water with small amount of gas).\r\nThe well was suspended on 11 March as an oil and gas appraisal well. The well was re-entered on 8 August 1995 with the semi-submersible installation \"Ross Isle\". The re-entry, 6608/10-3 R, was permanently plugged and abandoned as an oil and gas appraisal well.\r\n\u003c/p\u003e\r\n\u003cb\u003e\r\nTesting\r\n\u003c/b\u003e\r\n\u003cp\u003e \r\nOne drill stem test was performed in well 6608/10-3 in the Ile Formation (perforated interval 2617-2648 m). The well produced 1250 Sm3/D of oil with a density of 860 kg/m3 at standard conditions and 102500 Sm3/D of gas with a relative density of 0.65 (air=1.0) through a 60/64\" (23.44 mm) choke.\r\n\u003c/p\u003e\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"925","properties":{"OBJECTID":925,"wlbNpdidWellbore":2646,"wlbName":"25/8-8 S","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 25/8-8 S was\r\ndrilled to test the Paleocene Heimdal Formation sandstones (Tau Prospect)\r\nlocated southeast of the Jotun Field and north east of the Balder Field on the\r\neast margin of the South Viking Graben. The well was planned with flexibility\r\nto be sidetracked into two other reservoir segments from the same 13 3/8"\r\ncasing. The well proved oil in the target and two sidetracks were drilled. Well\r\n25/8-8 A was the first sidetrack and the objective was to appraise the discovery\r\nin the primary well and to evaluate the sand quality in the eastern segment of\r\nthe Tau Structure. Well 25/8-8 B was the second sidetrack and the objective was\r\nto appraise and evaluate resource potential in the western segment of the\r\n25/8-8 S Discovery and to confirm oil-water and possibly gas-oil contacts.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eExploration well\r\n25/8-8 S was spudded with the semi-submersible installation "Vildkat\r\nExplorer" on 22 August 1995 and drilled deviated to TD at 2592 m (2343.7 m\r\nTVD SS) in the Late Jurassic Draupne Formation. The well was drilled to 1058 m\r\nwith seawater and high viscosity gel pills. From 1058 m to TD the well was\r\ndrilled using an oil-based mud, "Safemul". MWD-GR-Res was used during\r\ndrilling. MWD-resistivity failed at 872 m and the hole was drilled to 1058 m\r\nwithout resistivity log. No shallow gas was observed. The 13 3/8" casing\r\nwas set at 1046.5 m.\u003c/p\u003e\r\n\r\n\u003cp\u003eWhen the second run\r\nwith the MDT was done, the MDT cable became stuck. The cable broke at the\r\ncasing shoe, leaving the tool and about 1000 m of cable in the hole. A fishing\r\njob was performed to get the tool and cable out. The fishing job was successful\r\nand the rest of the logging program was completed.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe target Heimdal\r\nFormation was penetrated at 2236 m and was found hydrocarbon bearing. A GOC is\r\nindicated within the interval 2244.9-2252.0 m (2057.0-2063.0 m TVD SS) based on\r\nELAN log analysis, pressure analysis and geochemical analyses. Av","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"926","properties":{"OBJECTID":926,"wlbNpdidWellbore":2661,"wlbName":"25/5-5","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eExploration well 25/5-5 is located a few\r\nkm east-southeast of the Heimdal field. The objective was the turbiditic sands\r\nof the Heimdal Formation, which is the reservoir for the Heimdal gas field. The\r\nJotun oil discovery (8 km south) and a minor oil discovery on 25/4-2 (5 km\r\nnorth-northwest) are also in Heimdal turbiditic sands. The prognosed TD of the\r\nwell was 2600 m in the Ty / Våle Formations in case of a discovery, or 2250 m\r\nin the Heimdal Formation, in case of a dry well. The chosen location was on the\r\nhighest structural point of the 25/5-5 closure. Oil with a possible gas cap was\r\nthe anticipated reservoir fluid\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 25/5-5 was spudded with the\r\nsemi-submersible installation Vildkat Explorer on 27 October 1995 and drilled\r\nto TD at 2600 m in the Paleocene Våle Formation. No significant operational\r\nproblems were encountered in this well and TD was reached in less than 9 days\r\nafter spud. The well was drilled with seawater and hi-vis pills down to 1206 m\r\nand with Safemul oil based mud from 1206 m to TD. Due to the choice of OBM\r\nsystem, the 8 1/2" diameter was drilled in preference to 12 1/4" to\r\nminimize mud and cuttings volumes. \u003c/p\u003e\r\n\r\n\u003cp\u003eTop Heimdal Formation was found at 2158.5\r\nm, 13 m above prognosis. The formation was 334 m thick. The reservoir was\r\noil-bearing, with an OWC at 2176.3 m. There was no recognised gas cap. As\r\nprognosed, the reservoir properties were very good. Two cores were cut from\r\n2162.5 m to 2199.75 m in sandstone of the Heimdal Formation. The cored interval\r\nwas hydrocarbon bearing, with the OWC clearly defined on the lower core. The\r\nMDT tool was run to obtain pressure and fluid samples from the reservoir.\r\nPressure depletion from production of the Heimdal Field was confirmed. From the\r\npressure plot some vertical barrier effects were evident in the deeper part of\r\nthe aquifer zone, below 2206 m. In the upper part of the Heimdal Sand, however,\r\nno pressure barriers c","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"927","properties":{"OBJECTID":927,"wlbNpdidWellbore":2666,"wlbName":"6204/10-1","wlbHistory":"\u003cb\u003e\r\nGeneral\r\n\u003c/b\u003e\r\n\u003cp\u003e\r\nThe objectives of well 6204/10-1 were to prove economic hydrocarbon reserves in the J-prospect (Turonian) and support play concept and possibly prove hydrocarbon reserves in the Jurassic lead. Further objectives were to achieve stratigraphic information and possibly prove reservoir sand and new play concepts in the Tertiary, Turonian and Cenomanian levels.\r\n\u003c/p\u003e\r\n\u003cb\u003e\r\nOperations and results\r\n\u003c/b\u003e\r\n\u003cp\u003e\r\nWell 6204/10-1 was spudded with the semi-submersible rig \"Deepsea Bergen\"on 28 October 1995 and drilled to 2709 m in basement rock within the planned budget. The 30\", 13 3/8\" and 9 5/8\" casing strings were successfully set. No drilling problems were encountered. The well was drilled with seawater / bentonite hi-vis pills / ANCO 2000 to 490 m and with KCl polymer mud from 490 m to TD. Four cores were cut, one in Tertiary and three in Cretaceous. No fluid samples were taken.\r\n\u003cbr\u003e\r\n\u003cbr\u003e\r\nThe well proved the geological model of the J- prospect. Unexpected conglomeratic sandstones devoid of fossils, probably eroded basement, were encountered in the lower part of the well and the well was terminated before reaching the planned TD.\r\n\u003cbr\u003e\r\nNo hydrocarbons were encountered, and the well was plugged and abandoned as a dry well.\r\n\u003c/p\u003e\r\n\u003cb\u003e\r\nTesting\r\n\u003c/b\u003e\r\n\u003cp\u003e\r\nNo drill stem test was performed.\r\n\u003c/p\u003e\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"928","properties":{"OBJECTID":928,"wlbNpdidWellbore":2667,"wlbName":"25/11-20","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 25/11-20 is\r\nlocated East of the Southern segment of the Grane field. The primary objectives\r\nof well 25/11-20 were to prove oil resources within reach of the Grane field\r\nproduction unit that can be produced through the Grane field installation and\r\nto test the geological and geophysical models for non-mounded Paleocene sands\r\nwithin the Licence area. The secondary objectives of well 25/11-20 were to\r\ndefine areas in the licence which can be relinquished and to reduce the uncertainties\r\nassociated with the surrounding prospects. The well location was selected to\r\nprovide an accurate seismic tie, i.e. an area with minimal compaction effects\r\nand away from faults, in an area where there are indications of a thick sand on\r\nthe seismic data.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 25/11-20 was\r\nspudded with the semi-submersible installation "Treasure Saga" on 8\r\nOctober1995 and drilled to TD at 1828 m in limestones of the Late Cretaceous\r\nTor Formation. The well was drilled water based with seawater and hi-vis bentonite\r\nsweeps down to 1254 m and with KCl / Polymer from 1254 m to TD. Unpredicted\r\nboulders were encountered at 152 m to 157 m, causing low ROP and extra work to\r\nkeep the inclination small, otherwise no significant problems were encountered\r\nduring drilling. Shallow gas was not predicted and not observed\u003c/p\u003e\r\n\r\n\u003cp\u003eNo sands or shows\r\nwere encountered in the Rogaland Group. An internal high acoustic impedance\r\nshale was present at depth 1683 m to 1705 m where Heimdal sands were prognosed.\r\nThe seismic response for this shale in the SOF data set was similar to the\r\nresponse for the Heimdal sand in the Grane Field. Four cores were cut between\r\n1661 m and 1719.5 m in the Balder, Sele, Lista, and Våle Formations. Coring was\r\nstopped 20 m under the prognosed top of the main sand. The well was permanently\r\nabandoned on 23 October 1995 as a dry hole. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test\r\nwas performed.\u003c/p\u003e\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"929","properties":{"OBJECTID":929,"wlbNpdidWellbore":2690,"wlbName":"25/8-8 A","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 25/8-8 S was\r\ndrilled to test the Paleocene Heimdal Formation sandstones (Tau Prospect)\r\nlocated southeast of the Jotun Field and north east of the Balder Field on the\r\neast margin of the South Viking Graben. The well was planned with flexibility\r\nto be sidetracked into two other reservoir segments from the same 13 3/8"\r\ncasing. The well proved oil in the target and two sidetracks were drilled. Well\r\n25/8-8 A was the first sidetrack and the objective was to appraise the discovery\r\nin the primary well and to evaluate the sand quality in the eastern segment of\r\nthe Tau Structure. Well 25/8-8 B was the second sidetrack and the objective was\r\nto appraise and evaluate resource potential in the western segment of the\r\n25/8-8 S Discovery and to confirm oil-water and possibly gas-oil contacts.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eExploration well\r\n25/8-8 S was spudded with the semi-submersible installation "Vildkat\r\nExplorer" on 22 August 1995 and drilled deviated to TD at 2592 m (2343.7 m\r\nTVD SS) in the Late Jurassic Draupne Formation. The well was drilled to 1058 m\r\nwith seawater and high viscosity gel pills. From 1058 m to TD the well was\r\ndrilled using an oil-based mud, "Safemul". MWD-GR-Res was used during\r\ndrilling. MWD-resistivity failed at 872 m and the hole was drilled to 1058 m\r\nwithout resistivity log. No shallow gas was observed. The 13 3/8" casing\r\nwas set at 1046.5 m.\u003c/p\u003e\r\n\r\n\u003cp\u003eWhen the second run\r\nwith the MDT was done, the MDT cable became stuck. The cable broke at the\r\ncasing shoe, leaving the tool and about 1000 m of cable in the hole. A fishing\r\njob was performed to get the tool and cable out. The fishing job was successful\r\nand the rest of the logging program was completed.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe target Heimdal\r\nFormation was penetrated at 2236 m and was found hydrocarbon bearing. A GOC is\r\nindicated within the interval 2244.9-2252.0 m (2057.0-2063.0 m TVD SS) based on\r\nELAN log analysis, pressure analysis and geochemical analyses. Av","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"930","properties":{"OBJECTID":930,"wlbNpdidWellbore":2695,"wlbName":"7/12-12 S","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 7/12-12 S was drilled as a reach-out\r\nwell from the Ula Platform to a fault block separate from the main Ula Field ca\r\n4 km south-southwest of the Platform location. The primary objective was to\r\ntest the reservoir and hydrocarbon potential in the Ula Formation. In the event\r\nof a discovery the plan was to complete the well as a producer.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eOperations on wildcat well 7/12-12 S\r\nstarted on 9 October 1995. The well was drilled from the Ula Platform and was kicked\r\noff at 547 m in existing development well 7/12-A-10 the 14th of November 1995. After drilling to 16"\r\nhole section TD at 2498 m the hole packed off and the string got stuck. Several\r\nattempts were made to retrieve the fish, but failed. A balanced kick-off plug\r\nwas set and the well was sidetracked (7/12-12 S T2) from 958 m and drilled to\r\nfinal TD at 6079 m (4067 m TVD) in interbedded sands, silts and shales of\r\npossible pre-rift age. The well was drilled with Enviromul oil based mud from\r\nkick-off to TD. Considerable hole problems occurred during drilling. There is a\r\ndiscrepancy of up to 7 m between drilled and logged depth below 5482 m. Depths\r\ngiven here are drilled depths.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eTop Reservoir (Ula Fm) was penetrated at\r\n6018 m MD (4020 m TVD), 118 m TVD deeper than predicted. Base Ula Formation was\r\npicked at 6067 m MD (4057 m TVD).Wire line logging and lack of shows proved a\r\ndry reservoir. Due to operational problems the planned open hole logging\r\nprogram was restricted to GR/Sonic and Resistivity.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo cores were cut and no wire line fluid\r\nsamples were taken.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was permanently abandoned on 17\r\nMarch 1996 as a dry well.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBod","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"931","properties":{"OBJECTID":931,"wlbNpdidWellbore":2696,"wlbName":"25/8-8 B","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 25/8-8 S was\r\ndrilled to test the Paleocene Heimdal Formation sandstones (Tau Prospect)\r\nlocated southeast of the Jotun Field and north east of the Balder Field on the\r\neast margin of the South Viking Graben. The well was planned with flexibility\r\nto be sidetracked into two other reservoir segments from the same 13 3/8"\r\ncasing. The well proved oil in the target and two sidetracks were drilled. Well\r\n25/8-8 A was the first sidetrack and the objective was to appraise the discovery\r\nin the primary well and to evaluate the sand quality in the eastern segment of\r\nthe Tau Structure. Well 25/8-8 B was the second sidetrack and the objective was\r\nto appraise and evaluate resource potential in the western segment of the\r\n25/8-8 S Discovery and to confirm oil-water and possibly gas-oil contacts.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eExploration well\r\n25/8-8 S was spudded with the semi-submersible installation "Vildkat\r\nExplorer" on 22 August 1995 and drilled deviated to TD at 2592 m (2343.7 m\r\nTVD SS) in the Late Jurassic Draupne Formation. The well was drilled to 1058 m\r\nwith seawater and high viscosity gel pills. From 1058 m to TD the well was\r\ndrilled using an oil-based mud, "Safemul". MWD-GR-Res was used during\r\ndrilling. MWD-resistivity failed at 872 m and the hole was drilled to 1058 m\r\nwithout resistivity log. No shallow gas was observed. The 13 3/8" casing\r\nwas set at 1046.5 m.\u003c/p\u003e\r\n\r\n\u003cp\u003eWhen the second run\r\nwith the MDT was done, the MDT cable became stuck. The cable broke at the\r\ncasing shoe, leaving the tool and about 1000 m of cable in the hole. A fishing\r\njob was performed to get the tool and cable out. The fishing job was successful\r\nand the rest of the logging program was completed.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe target Heimdal\r\nFormation was penetrated at 2236 m and was found hydrocarbon bearing. A GOC is\r\nindicated within the interval 2244.9-2252.0 m (2057.0-2063.0 m TVD SS) based on\r\nELAN log analysis, pressure analysis and geochemical analyses. Av","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"932","properties":{"OBJECTID":932,"wlbNpdidWellbore":2699,"wlbName":"2/1-11","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 2/1-11 is located on the Hidra High\r\nin the Central Graben of the North Sea. It was drilled to investigate the\r\npossibility of commercial quantities of hydrocarbons in the Jurassic J60/J70\r\nsandstones (Ula Formation). A secondary objective was to assess the reservoir\r\npotential of the older J50 Jurassic sandstone sequence.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 2/1-11 was spudded with the\r\nsemi-submersible installation Mærsk Jutlander on 14 January 1997 and drilled to\r\nTD at 4725 m (4697 m TVD) in the Late Triassic Smith Bank Formation. At a depth\r\nof 724 m, while drilling riserless, the well was observed by the ROV to be flowing.\r\nEvidence of this flow was observed in the moon pool - a patch of light coloured\r\nwater being apparent. The well was circulated with seawater while additional\r\nkill mud was built. A pilot hole was then drilled to the section TD of 1151 m with\r\nfurther flows being observed at 736 m, 802 m, 900 m, 939 m, 1112 m and 1121 m. Most\r\nlikely the gas in all instances came from an interval between 650 and 724 m,\r\nwhich after drilling was correlated to a shallow biogenic gas warning at 638\r\nidentified in the site survey. The shallow gas problems led to a delay in\r\ninstalling a new cuttings handling system on the rig, required because of a\r\nlate decision to use oil based mud in the 12 1/4" hole. No serious harm\r\nwas done by the shallow gas but considerable rig time was spent. The well was\r\nplanned vertical but a slight deviation is seen in the deviation survey,\r\nstarting at ca 3600 m (3 deg deviation). At 4350 m the deviation had reached 10\r\ndeg, and at TD it was 30 deg. As a result MD is more than 5 m larger than TVD\r\nbelow 4450 m, and the difference is as much as 28 m at TD. The well was drilled\r\nwith seawater and hi-vis sweeps down to 1162 m and with ENVIROMUL oil based mu","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"933","properties":{"OBJECTID":933,"wlbNpdidWellbore":2701,"wlbName":"25/11-21 S","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 25/11-21 S was\r\ndrilled on the Grane Field. The primary objectives of well 25/11-21 S were to\r\ncalibrate the depth conversion model with reference to top and base of the\r\nGrane reservoir and the oil-water contact, and to investigate horizontal and\r\nvertical reservoir barriers and reservoir heterogeneities. The secondary\r\nobjectives of well 25/11-21 S were to obtain reservoir and fluid data and to\r\ninvestigate uncontaminated initial water saturation values in the oil zone. The\r\nwell location was selected to allow building up hole angle for later drilling\r\nof a horizontal section (25/11-21 A) at the required depth and coordinates and\r\nat the same time to provide an accurate seismic tie, i.e. an area with minimal\r\ncompaction effects and away from faults, in an area where there are indications\r\nof a thick sand on the seismic data.\u003c/p\u003e\r\n\r\n\u003cp\u003eSidetrack well 25/11\r\n-21 A was drilled to obtain 600 m to 900 m of horizontal reservoir information.\r\nThe objectives were to appraise the reservoir in terms of reservoir quality and\r\nto confirm the structural top and base reservoir maps; to obtain lateral\r\nvelocity information for calibration of the depth conversion model; to identify\r\npossible reservoir heterogeneities indicated on seismic; and finally to perform\r\nan extended test production in the horizontal section of the well. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eAppraisal well\r\n25/11-21 S was spudded with the semi-submersible installation "Treasure\r\nSaga" on 23 October 1995 and drilled to TD at 1957 m (1863.5 m TVD MSL) in\r\nLate Cretaceous Hod Formation. The well was drilled with seawater and hi-vis\r\nbentonite sweeps down to 1270 m and with KCl / Polymer mud from 1270 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eHeimdal Formation\r\nsand was penetrated at 1788 m (1711.5 m TVD MSL). A reservoir thickness of 88 m\r\n(79.5 m TVD) was defined, giving a net pay of 57.9 m. The pressure data from\r\nthe Heimdal Formation indicates a 0.4 bar pressure difference to well 25/11-18\r\nT2 and 1.7 bar difference to ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"934","properties":{"OBJECTID":934,"wlbNpdidWellbore":2703,"wlbName":"16/10-3","wlbHistory":"\u003cb\u003e\r\nGeneral\r\n\u003c/b\u003e\r\n\u003cp\u003e\r\nWell 16/10-3 was drilled as an exploration well on the \"Tyr Central prospect\" located near the block boundary in the northeast part of the Block in Production License 101. The licence was awarded in 1985, after the 9th concession round.\r\n\u003c/p\u003e\r\n\u003cp\u003e\r\nThe purpose of drilling well 16/10-3 was to test the hydrocarbon potential of the Middle Jurassic/Triassic reservoir (Hugin and Skagerrak Formations) in the Tyr structure. The tested structure consisted in several culminations with a common dip closure. The well location was set on the largest of these, called \"Tyr Central\". The well was drilled by Norsk Agip as operator and was a joint well with the licence holders of PL 072.\r\n\u003c/p\u003e\r\n\u003cb\u003e\r\nOperations and results\r\n\u003c/b\u003e\r\n\u003cp\u003e\r\nExploration well 16/10-3 was spudded with the jack-up installation \"Transocean Nordic\" on 22 October 1996 and drilled to a total depth of 2850 m in the Triassic Smith Bank Formation shales. The well was drilled/cased/logged and abandoned in 40 days but due to WOW (wait on weather) the rig was not released from its contract and moved off location until the 6 December 1996 after a total of almost 51 days. The well was drilled with spud mud down to 196 m, with Seawater and PAC hi-vis sweeps from 196 m to 431, and with KCl / PAC glycol mud from 431 m to TD.\r\n\u003c/p\u003e\r\n\u003cp\u003e\r\nAll the expected formations were encountered. The Jurassic/Triassic sands were found with fair reservoir quality. The expected reservoir was encountered at 2521 m, 31 m deeper than prognosis. The Hugin-Skagerrak sands were found water bearing and no hydrocarbon shows were detected. No relevant gas amounts were recorded in the well and no hydrocarbon shows were identified on cuttings in the reservoir section. Two FMT fluid samples were collected at two different depths: the recovery was mud filtrate in the first sample at 2522 m and mud in the second one at 2544.3 m. No conventional cores were cut in this well. The well was permanently abandoned as a dry well on 1 December 1996.\r\n\u003c/p\u003e\r\n\u003cb\u003e\r\nTesting \r\n\u003c/b\u003e\r\n\u003cp\u003e\r\nNo d","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"935","properties":{"OBJECTID":935,"wlbNpdidWellbore":2719,"wlbName":"30/8-1 SR","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 30/8-1 SR is a re-entry of well\r\n30/8-1 S in the Viking Graben of the North Sea, just west of the Oseberg\r\nFields.\u003c/span\u003e\u003cspan lang=EN-US\u003eThe objective of the original\r\n30/8-1 S well was to \u003c/span\u003e\u003cspan lang=EN-GB\u003etest the hydrocarbon potential of\r\nthe Jurassic Brent Group and Statfjord Formation with the additional commitment\r\nto drill into the Hegre Group or to a maximum depth of 5026 m TVD. Well 30/8-1\r\nS discovered gas/condensate in the Tarbert Formation of the Brent Group, but\r\nwas suspended on 1 March 1995 due to environmental regulations. The re-entry 30/8-1\r\nSR should complete the programme for 30/8-1 S.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 30/8-1 SR was re-entered and spudded\r\nwith the semi-submersible installation on 14 November 1995 and drilled to TD at\r\n5149 m (4767 m TVD) in the Statfjord Formation. Drilling activities took 9 days\r\nmore than budget, due mainly to a wear-hole in the casing and fishing for lost\r\nlogging tools. A core was attempted at core point 5145 m in the Statfjord\r\nFormation. After coring to 5149 m the core the BHA was pulled, but both core\r\nand barrel was lost in hole. Fishing was unsuccessful and 5149 m became final\r\nTD. The well was drilled water based with ANCO 2000 mud from 4668 m to 4710 m\r\nand with Ancoterm High Temperature mud from 4710 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe Statfjord Formation was the only new formation\r\npenetrated by the re-entry. Based on logs and one core gas was identified in\r\nthe Statfjord Formation down to 4859.0 m (4497 m TVD) (gas-down-to contact). Based\r\non MDT-pressure data, the initial reservoir pressure was interpreted to be 778\r\nBar at 4696.6 m (4356 m TVD). In the Statfjord Formation a total of 98.0 m\r\n(true stratigraphical thickness) net gas pay was interpreted with an average\r\nlog calculated porosity of","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"936","properties":{"OBJECTID":936,"wlbNpdidWellbore":2723,"wlbName":"30/8-2","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 30/8-2 was drilled in the Viking\r\nGraben of the North Sea, about mid-way between the Hild and the Oseberg Sør Fields.\r\nThe objective was to test the hydrocarbon potential of the Tertiary X1 prospect.\r\nThe main target was a prognosed Heimdal Formation sand within the Lista\r\nFormation. Planned TD was at 2404 m in the uppermost Cretaceous.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 30/8-2 was spudded with the\r\nsemi-submersible installation West Vanguard on 15 December 1995 and drilled to\r\nTD at 2405 m in the Late Cretaceous Jorsalfare Formation. Indications of shallow\r\ngas was observed as low gamma and high resistivity in a thin sand layer at 386\r\nm. No significant problems were encountered in the operations. The well was\r\ndrilled with spud mud down to 1542 m and with KCl/polymer mud from 1542 m to\r\nTD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe prognosed Heimdal Formation was not\r\npresent in the well but a sandstone rich interval assigned to the Hermod\r\nFormation was encountered. In the Hermod Formation, a total of 31 m net\r\nreservoir sand was calculated between 2075.5 m and 2137.5 m. A Petroleum\r\nGeochemistry Study of the reservoir interval indicated significant amounts of\r\nmigrated hydrocarbons in the Hermod Formation. Traces of migrated hydrocarbons were\r\ndetected also in thinner sands in the Balder and Våle Formations. The reservoir\r\nproperties were excellent. An average porosity of approximately 30% has been\r\ncalculated based on petrophysical evaluation. Permeabilities greater than 3500\r\nmD are measured from core plugs. The hydrocarbon saturation is low and no\r\nevidence for moveable hydrocarbons was found in the log data. Fair to weak\r\nshows were recorded on cuttings from sandstones and limestone stringers from\r\nTop Balder Formation to TD, and good oil shows were recorded on sandston","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"937","properties":{"OBJECTID":937,"wlbNpdidWellbore":2728,"wlbName":"25/10-6 S","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 25/10-6 S is\r\nlocated West-Southwest of the Balder field. The main objectives for the well\r\nwere to prove the hydrocarbon potentials of the Heimdal, Ty, and the Hugin\r\nFormations.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 25/10-6\r\nS well was spudded with the semi-submersible installation "Deepsea\r\nBergen" on 26 December 1995 and drilled deviated to a TD of 4706 m (4281.5\r\nm TVD) in the Middle Jurassic Sleipner Formation. The well was drilled using\r\nbentonite / CMC EHV mud down to 1039 m, with "ANCO 2000" mud from\r\n1039 m to 2377 m, and with oil based "ANCOVERT" mud from 2377 m to\r\nTD. Several drilling problems were encountered below 1339 m and it took 30 days\r\nmore than budget to reach TD. The problems included mud pump failure, MWD failure\r\nand difficulties with controlling the angle, bad weather, and bit problems.\r\nMany of the problems were due to hard formation. The well was drilled\r\nvertically to 1631 m before building angle.\r\n\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 25/10-6 S\r\ndrilled through sediments of Tertiary, Cretaceous and into Jurassic ages. The\r\nwell penetrated the Heimdal Formation at 2317.5 m and the Ty Formation at\r\n2636.5 m. The angle was then approximately 15.5°. The angle increased through\r\nthe Shetland Group and reached a maximum of 43.5° at approximately 4330 m in\r\nthe Vestland Group. The well penetrated the Hugin Formation at 4337.5 m (3995.5\r\nm TVD), 41.5 m deeper than prognosed (at an angle of 42°). The potential\r\nreservoirs in Palaeocene sandstones (Heimdal and Ty Formations) were water\r\nbearing. The Hugin Formation contained hydrocarbons, but the core data and\r\nFMT-results showed tight formation. Three cores were cut in the Hugin\r\nFormation. Of these, a total of only 12.7 m core were recovered because a very\r\nhard formation wore out the bit earlier than expected No fluid samples were\r\ncollected. The well was permanently plugged and abandoned on 22 March 1996 as a\r\ndry well with shows.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"938","properties":{"OBJECTID":938,"wlbNpdidWellbore":2733,"wlbName":"34/11-2 S","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 34/11-2 S was drilled on the Tjalve\r\nTerrace east of the Gullfaks Field in the northern North Sea. The main\r\nobjective was to explore the hydrocarbon potential of the Middle Jurassic Brent\r\nGroup reservoirs within the Beta structure. The secondary objective was to test\r\nfor hydrocarbons in the Lower Jurassic/Triassic Statfjord Formation.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 34/11-2 S was spudded with\r\nthe semi-submersible installation Vildcat Explorer on 16 January 1996 and\r\ndrilled to TD at 4743 m in the Early Jurassic Statfjord Formation. The well was\r\ndrilled practically vertical down to ca 3139 m, ca 140 m below the 13 3/8"\r\ncasing shoe, and deviated from this point. The drilling of the well was not\r\nperformed within the plan due to lost time as a consequence of bad weather,\r\nsteering and building angle in 12 1/4" hole section, extended logging,\r\nextended well and equipment failure. The well was drilled with pre-hydrated\r\nbentonite, seawater and bentonite sweeps down to 1170 m, with ANCO 2000 mud\r\nwith 3.4 to 5.2% glycol from 1170 m to 3766 m, and with a KCl/polymer mud\r\nsystem from 3766 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eOil was proven by MDT fluid sampling in a\r\nthin sand bed at 3797.5 m (3756.2 m TVD) above the main Brent Group reservoir.\r\nThe Bathonian age of these sand beds imply that they belong to the upper part\r\nof the Brent Group. Sliding or faulting of huge blocks along the foot wall of\r\nthe main fault could explain the presence of this Allochtonous "Brent\r\nGroup" above the Heather Formation. Top of the main objective the Brent\r\nGroup was penetrated at 4068.0 m \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003e(3422.1 m TVD), 252 m deeper than the\r\nprognosis. Pressure measurements indicated hydrocarbon fluids present in the\r\nentire","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"939","properties":{"OBJECTID":939,"wlbNpdidWellbore":2736,"wlbName":"6506/11-4 S","wlbHistory":"\r\n\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003e\u00A0Well 6506/11-4 S was drilled on the\r\nsouthern segment of the Smørbukk Discovery. The objectives of the well were to\r\nappraise the Smørbukk Discovery and to verify the planned production in the\r\nsouthern segment. The well was planned to be completed as a future producer.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 6506/11-4 S was spudded with\r\nthe semi-submersible installation Transocean Searcher on 11 February 1996 and\r\ndrilled to TD at 5110 m (4887.5 m MSL) in Early Jurassic sediments of the Åre\r\nFormation. The hole was drilled to 4531 m in the Garn Formation and the 9\r\n5/8" casing was set at planned depth, with casing shoe a few meters into\r\nthe Garn Formation. However, during drilling out of casing, the new 8 1/2"\r\nbottom hole assembly was seized by late setting cement and got stuck inside\r\ncasing. The well was side tracked with KOP at approximately 3144 m. The\r\nsidetrack is designated 6506/11-4 S T2. The sidetrack leg was drilled to the\r\noriginal target zone, the Åre Formation. The well was drilled with seawater and\r\nbentonite down to 1415 m, with KCl/polymer/Anco200 from 1415 m to 2825 m and\r\nwith Ancovert oil based mud from 2825 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eA Lange Formation sandstone unit was\r\nencountered from 4236 m to 4321 m. Well bore 6506/11-4 S T2 penetrated the top\r\nof the Tilje Formation and the Åre Formation approximately 24 m deeper than\r\nprognosed. Logs proved hydrocarbons in the Garn Formation, the Ile Formation\r\nand in the Åre 2 reservoir zone. The Tilje 1.1 Reservoir Zone was found to be\r\nwater bearing. Hydrocarbons were further indicated by high resistivity log\r\nreadings in the Lange Formation sandstone unit and in interbedded sandstones in\r\nthe Lysing Formation from 3571 m to 3603 m.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eTwo ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"940","properties":{"OBJECTID":940,"wlbNpdidWellbore":2769,"wlbName":"25/10-7 S","wlbHistory":" \u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n \r\n \u003cp\u003eWell 25/10-7 S is\r\n located southwest of the Balder area. The primary objective of the well was to\r\n evaluate resource potential in the Paleocene Heimdal Formation in the Bjørn\r\n Prospect. Secondary objective was to evaluate resource potential in the Lower\r\n Eocene interval based on a high amplitude seismic response. \u003c/p\u003e\r\n \r\n \u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n \r\n \u003cp\u003eExploration well\r\n 25/10-7 S was spudded with the semi-submersible installation "Vildkat\r\n Explorer" on 20 May 1996 and drilled to TD at 2617 m (2582 m TVD) in the\r\n Early Paleocene Ekofisk Formation. The well was drilled with seawater and\r\n bentonite down to 1102 m and with "ANCOVERT" oil based mud from 1102\r\n m to TD. The well was drilled deviated to avoid shallow gas at a depth of\r\n 512-822 meters below sea level close to the proposed location. The surface\r\n location of 25/10-7 S was moved approximately 200 m south of the reservoir\r\n target location, and no shallow gas was seen at this location. The well was\r\n drilled vertically to 1165 m where angle was gradually built to max 25.8\r\n degrees and then again reduced to 1& at 2000 m. Well time for 25/10-7 S was\r\n 19.78 days (vs. 31 days targeted) for $4.7 M (vs. an AFE of $6.7 M). A major\r\n contribution to the reduced time and cost was a reduction of the electric\r\n logging program from the planned 4 days to the actual of 0.6 days due to a\r\n labour dispute involving key service companies in Norway. A 233 m thick Heimdal\r\n Formation was penetrated by the well, starting at 2238 m. The secondary, Eocene\r\n target was a 22 m thick limestone. The plan was to cut one core in the top of\r\n the Heimdal sand, regardless of hydrocarbon shows. Coring continued after core\r\n no.2 based on shows described at well site. A total of five cores were cut from\r\n 2200-2378 m from the Lista Formation through a complete Heimdal sequence and\r\n into the Lista Formation again. Subsequent to the coring MWD logs reamed across\r\n cored interval showed reservoir to be water wet. ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"941","properties":{"OBJECTID":941,"wlbNpdidWellbore":2772,"wlbName":"35/11-8 S","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 35/11-8 S is located ca 15 km due\r\nnorth of the Troll Field. It was designed to test the hydrocarbon potential in\r\nthe H-structure located in a down-faulted position west of the F/C complex\r\nwhere oil and gas was discovered in the wells 35/11-4 and -7. The main targets\r\nwere the Brent Group and the Sognefjord Formation equivalent. Possible\r\nsecondary targets were seen in Intra Draupne sandstone and a mound feature in\r\nthe Paleocene sequence.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 35/11-8 S was spudded with\r\nthe semi-submersible installation Treasure Saga on 3 March 1996 and drilled to\r\nTD at 3624 m (3355 m TVD RKB) m in the Early Jurassic Drake Formation. The well\r\nwas drilled vertically in the top hole, starting to build angle below the 30"\r\ncasing shoe at 447 m. From 950 m to 2250 m the deviation was kept at 31 ± 2°,\r\nfrom which point the inclination was gradually reduced towards a more vertical\r\npath. After the testing phase, operations were interrupted for some three days\r\nby an industrial strike. Operations went without significant technical\r\nproblems. The well was drilled with spud mud down to 1233 m and with\r\nKCl/polymer mud from 1233 m to TD. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe Paleocene mound feature proved to\r\nconsists of 66 m of water bearing sand with weak shows in the uppermost part.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe prognosed lead related to the high\r\namplitude Intra Draupne reflector corresponded to the Late Jurassic source\r\nrock. A thin sandstone at the base of the Sognefjord Formation was water filled\r\nwith weak shows. Oil and gas was discovered in a 115 m thick Late Jurassic\r\nturbiditic sandstone unit at 2860 m. The sequence could not be correlated with\r\nthe Sognefjord Formation in the neighbouring wells and is classified as an\r\nIntra Heather Sandstone unit. From 2860 to 2881 m 20.7 m net pay gas reservoir\r\nshowed a gas saturation of 89 % and the average porosity was calculated to 21.9\r\n%. A 40.1 m net pay oil zone was calculated for the interval between 2881m and\r\n2938 m.","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"942","properties":{"OBJECTID":942,"wlbNpdidWellbore":2783,"wlbName":"35/10-2","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 35/10-2 is located on the\r\nFlatfisk Slope approximately mid-way between the Fram and the Kvitebj ørn\r\nDiscoveries in the Northern North Sea. The primary objective for the well was\r\nto explore the hydrocarbon potential of the Middle Jurassic Brent reservoir.\r\nThe secondary objective was to explore the hydrocarbon potential of the\r\nPaleocene sandstones of the Goliath -prospect. Furthermore, the well would test\r\nthe reservoir potential of the "intra Dunlin" (Cook Formation) and\r\nStatfjord sandstones. Planned TD was 5000 m MSL.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 35/10-2 was spudded with the\r\nsemi-submersible installation Transocean Arctic on 16 April 1996. The original\r\nwell path, 35/10-2, was drilled down to a total depth of 3301 m, where the mud\r\nmotor parted. A technical sidetrack, named 35/10-2 T2 was necessary. This was\r\nkicked off at 2563 and the well was drilled down to TD for the well at 4677 m\r\nin the Early Jurassic Statfjord Formation. In the 8 3/8" section, severe\r\nproblems were encountered due to mud losses. The hole was cemented back once to\r\ntry and seal off the loss zones. The well was drilled with bentonite down to\r\n1460 m, with ANCO 2000 mud from 1460 m to 3990 m, and with AncoTherm mud from\r\n3990 m to TD\u003c/p\u003e\r\n\r\n\u003cp\u003eNo reservoir quality sandstones of any\r\nthickness were found in the Tertiary. The seismic anomaly thought to represent\r\nthe Goliath prospect, was in fact caused by a sequence of thin siltstones and\r\nvery fine sandstones at 1953-1955 m in the Sele Formation. Good oil shows were\r\nobserved in this interval. The top of the Brent Group was penetrated at 4149 m,\r\nalmost 90 m higher than prognosed, and the reservoir proved to hold a gas\r\ncolumn of approximately 72 m. The well penetrated sandstones in the Early\r\nJurassic, (Cook, Amundsen and Statfjord Formations), but no hydrocarbons were\r\nobserved in these. Due to this the well was not drilled to the planned TD. \u003c/p\u003e\r\n\r\n\u003cp\u003eNine conventional cores were cut in the\r\nwell","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"943","properties":{"OBJECTID":943,"wlbNpdidWellbore":2794,"wlbName":"6506/11-5 S","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThe main objectives of the well 6506/11-5\r\nS were to appraise hydrocarbons in the Smørbukk Field and collect data on\r\nreservoir quality and fluid distribution, to act as an observation well during\r\nthe long-term test/ interference test of well 6506/12-11 S R, and to be an\r\ninjector well on the Smørbukk Field. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThe deviated appraisal well 6506/11-5 S\r\nwas spudded on 10 September 1996 with the semi-submersible installation\r\n"Transocean Searcher" and drilled to a TD of 4740 m in the Åre\r\nFormation. The well was drilled with seawater and high viscosity pills down to\r\n622 m, Anco 2000 with glycol from 622 to 2140 m, and with oil based Anco vert\r\nfrom 2140 m to TD. Unexpected high formation pressure was encountered at TD and\r\nthe mud weight was raised according to this. The Tilje reservoir zone and Åre 2\r\nFormation proved to be hydrocarbon bearing as expected. Three cores (179 meter\r\ncored and recovered) were cut from the Tilje and Åre Formations. Two MDT fluid\r\nsamples were taken at 4674 m in the Tilje Formation. The well was suspended on\r\n10 November 1996 as an observation well for an extended test to be carried out\r\nin well 6506/12-11 S R. The well was then re-classified from oil and gas\r\nappraisal well to development well 6506/11-G-1 H. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting \u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was perforated in the Tilje 1.1\r\nReservoir Zone (4671 - 4685 m) and permanent pressure gauges were installed.\r\nOnly a short clean up flow was carried out before the pressure gauges were\r\ninstalled so no flow rates were recorded. Due to technical problems with the\r\npressure test string the test was abandoned and no pressure data to confirm\r\ncommunication with well 6506/12-11 S R was obtained.\u003c/p\u003e\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"944","properties":{"OBJECTID":944,"wlbNpdidWellbore":2795,"wlbName":"6506/12-11 S","wlbHistory":"\u003cb\u003e\r\nGeneral\r\n\u003c/b\u003e\r\n\u003cp\u003e\r\nThe well 6506/12-11 S was planned to be completed as a future producer. The main objectives of the well were to collect data on reservoir quality and fluid distribution, perform a long-term test to evaluate the continuity of the reservoir in the Tilje Formation, carry out an interference test between this well and an adjacent gas injector, 6506/11-5 S, and to investigate the effect of stimulation by fracturing on well productivity.\r\n\u003c/p\u003e\r\n\u003cb\u003e\r\nOperations and results\r\n\u003c/b\u003e\r\n\u003cp\u003e\r\nThe deviated appraisal well 6506/12-11 S was spudded on 8 June 1996 with the semi-submersible installation \"Transocean Searcher\" and drilled to a TD of 5268 m (4842.5 m TVD), approximately 60 m into the Åre Formation. Drilling was interrupted for 11 days by a labour conflict. The well was drilled with seawater and high viscosity pills down to 621 m, Anco 2000 mud with glycol from 621 to 2242 m, and with oil based Anco vert from 2242 m to TD.\r\nThe well penetrated the top of the Tilje Formation and the Åre Formation, respectively, 18 m and 9.5 m shallower than prognosed. Both the Tilje and the Åre Formations were hydrocarbon bearing. Two tests were performed, one in Åre and one in Tilje. In addition, a minifrac test was performed in the Åre Formation. Six cores (196 m, 187 m recovered) were cut in the Tilje and Åre Formations. Three MDT wireline samples were taken in the well, one from each of the formations Åre, Tilje, and Garn. The samples from the Tilje and Åre Formations contained oil and gas, while the sample from the Garn Formation, contained formation water.\r\nA 7\" liner was run and cemented on 9 August 1996.\r\nAfter testing, well 6506/12-11 S was suspended on 7 September 1996 as an oil appraisal well. The well was re-entered (6506/12-11 SR) on 11 November 1996 for an extended test. Well 6506/12-11 SR was suspended as an oil appraisal well on 1 February 1997 and re-classed to development well 6506/12-I-4 H.\r\n\u003c/p\u003e\r\n\u003cb\u003e\r\nTesting\r\n\u003c/b\u003e\r\n\u003cp\u003e \r\nTest 1 in 6506/12-11 S was carried out over the interval 5226 - 5235.5 m ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"945","properties":{"OBJECTID":945,"wlbNpdidWellbore":2796,"wlbName":"6407/1-4","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 6407/1-4 was drilled primarily to\r\nappraise the 6407/1-3 Tyrihans Nord Discovery. The specific target was to\r\nencounter a free oil-water-contact in the Garn Formation. Secondary objective\r\nwas to gather information from the possibly oil bearing Campanian sandstone\r\ninterval (Nise Formation).\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eAppraisal well 6407/1-4 was spudded with\r\nthe semi-submersible installation Byford Dolphin on 6 June 1996 and drilled to\r\nTD at 3805 m in the Middle Jurassic Not Formation. Due to a labour conflict the\r\nMWD services was not run in the top hole down to 810 m. In addition 183 hrs rig\r\ntime was lost during the strike. The well was drilled with seawater and\r\nprehydrated bentonite sweeps down to 816 m, from 816 m to 1810 m with ANCO 2000\r\nmud, and with oil based Ancovert mud from 1810 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe upper part of the Nise Formation was\r\ndominated by siltstone with abundant thin laminas of very fine sandstone and\r\nrare limestone stringers. From 2560 m the siltstone progressively grades to\r\nclaystone, becoming 100 % claystone at 2620 m. Top Garn reservoir came in 101 m\r\nthick at 3675 m, 18 m deep to prognosis, so rock-volume above proven OWC was\r\nreduced. The reservoir was more cemented than expected. Trace fluorescence and\r\ncrush cut was recorded in a single siltstone cutting sample from the Springar\r\nFormation at 2470 m, otherwise no shows were seen above the shales and\r\nclaystones of the Late Jurassic Spekk and Melke Formations. Gas on oil on water\r\nwas encountered in the Garn Formation reservoir. The gas/oil contact was at\r\n3681 m, while the oil/water contact was at 3705 m. No shows were recorded below\r\nthe OWC. One conventional core was cut from 2498 m to 2526 m in the Nise\r\nFormation. Two conventional cores were cut across both fluid contacts from\r\n3679.0 m to 3740.0 m in the Garn Formation, A FMT water sample was taken below\r\nthe OWC at 3709 m. Two segregated FMT samples were taken to collect gas (3679.2\r\nm) and oil (3691.2 m).\u003c/p\u003e\r\n\r\n\u003c","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"946","properties":{"OBJECTID":946,"wlbNpdidWellbore":2798,"wlbName":"31/2-19 S","wlbHistory":"\u003cb\u003e\r\nGeneral\r\n\u003c/b\u003e\r\n\u003cp\u003e\r\nWell 31/2-19 S is located in the Troll West area some few kilometres to the northwest of the Troll Field. It was drilled to test the hydrocarbon potential of the \"S-structure\". The primary targets were the Jurassic Sognefjord and Fensfjord Formations, and the Brent Group. Secondary targets were the Paleocene (Lista Formation), the Dunlin Group and the Statfjord Formation.\r\n\u003c/p\u003e\r\n\u003cb\u003e\r\nOperations and results\r\n\u003c/b\u003e\r\n\u003cp\u003e\r\nExploration well 31/2-19 S was spudded with the semi-submersible installation \"West Vanguard\" on 8 May and drilled to TD at 4114 m (3669 m TVD RKB) in the Early Jurassic Statfjord Formation The well was drilled with seawater and hi-vis bentonite sweeps down to 1316 m and with KCl/PHPA polymer mud from 1316 m to TD.\r\n\u003c/p\u003e\r\n\u003cp\u003e\r\nThe well encountered 131 m of Intra Lista Formation sandstone, and a 30-40 m sandy interval of poor reservoir quality in the Cretaceous Rødby Formation. Two of the primary prospective levels, the Sognefjord and Fensfjord Formations of the Viking Group were not deposited; instead more than 700 m with the distal Heather formation was penetrated. The Brent Group and Dunlin Group sandstones, and the Statfjord Formation were encountered according to the prognosis. The well was found to be dry (no moveable hydrocarbons) with only weak hydrocarbon shows observed in the Intra Lista Formation sandstone and in sandstones of the Viking and Brent Groups.\r\n\u003c/p\u003e\r\n\u003cp\u003e\r\nFive cores were cut, two of them in the Lista Formation, the third in the Rødby Formation, and the last two ones in the Heater Formation. Pressure points were obtained by the HP gauge of the RFT tool. In the Lista Sandstone, a water gradient of 0.99 g/cc was found. In the Cretaceous, no gradient could be defined due to only tight points. In the Brent Group (the Ness and Etive formation equivalents) a water gradient of 1.01 g/cc was found. In the Dunlin Group three good RFT points were achieved. The two deepest ones (in the Amundsen Formation) indicated a water gradient of 0.98 g/cc. No fluid samples we","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"947","properties":{"OBJECTID":947,"wlbNpdidWellbore":2812,"wlbName":"25/11-21 A","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 25/11-21 S was\r\ndrilled on the Grane Field. The primary objectives of well 25/11-21 S were to\r\ncalibrate the depth conversion model with reference to top and base of the\r\nGrane reservoir and the oil-water contact, and to investigate horizontal and\r\nvertical reservoir barriers and reservoir heterogeneities. The secondary\r\nobjectives of well 25/11-21 S were to obtain reservoir and fluid data and to\r\ninvestigate uncontaminated initial water saturation values in the oil zone. The\r\nwell location was selected to allow building up hole angle for later drilling\r\nof a horizontal section (25/11-21 A) at the required depth and coordinates and\r\nat the same time to provide an accurate seismic tie, i.e. an area with minimal\r\ncompaction effects and away from faults, in an area where there are indications\r\nof a thick sand on the seismic data.\u003c/p\u003e\r\n\r\n\u003cp\u003eSidetrack well 25/11\r\n-21 A was drilled to obtain 600 m to 900 m of horizontal reservoir information.\r\nThe objectives were to appraise the reservoir in terms of reservoir quality and\r\nto confirm the structural top and base reservoir maps; to obtain lateral\r\nvelocity information for calibration of the depth conversion model; to identify\r\npossible reservoir heterogeneities indicated on seismic; and finally to perform\r\nan extended test production in the horizontal section of the well. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eAppraisal well\r\n25/11-21 S was spudded with the semi-submersible installation "Treasure\r\nSaga" on 23 October 1995 and drilled to TD at 1957 m (1863.5 m TVD MSL) in\r\nLate Cretaceous Hod Formation. The well was drilled with seawater and hi-vis\r\nbentonite sweeps down to 1270 m and with KCl / Polymer mud from 1270 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eHeimdal Formation\r\nsand was penetrated at 1788 m (1711.5 m TVD MSL). A reservoir thickness of 88 m\r\n(79.5 m TVD) was defined, giving a net pay of 57.9 m. The pressure data from\r\nthe Heimdal Formation indicates a 0.4 bar pressure difference to well 25/11-18\r\nT2 and 1.7 bar difference to ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"948","properties":{"OBJECTID":948,"wlbNpdidWellbore":2823,"wlbName":"24/12-3 S","wlbHistory":"\u003cb\u003e\r\nGeneral\r\n\u003c/b\u003e\r\n\u003cp\u003e\r\nThe main objective for the well was to test the hydrocarbon potential in the Paleocene Heimdal Formation on the A-Heimdal Prospect.\r\n\u003c/p\u003e\r\n\u003cb\u003e\r\nOperations and results\r\n\u003c/b\u003e\r\n\u003cp\u003e\r\nWell 24/12-3S was spudded on 27 June 1996 with the semi submersible drilling rig \"Deepsea Trym\" and reached TD at 3058 m (2751 m TVD RKB) in the Paleocene Våle Formation on 23 July 1996. The well was drilled water based with bentonite spud mud down to 1130 m and with ANCO 2000 mud from 1130 to TD. Geochemical analyses indicated that the water based mud contained traces of oil, which did not originate from the reservoired oil in the well.\r\n\u003cbr\u003e\r\n\u003cbr\u003e\r\nThe well proved 2.8m TVD of hydrocarbons in the top of the Heimdal Formation. This has been deducted from FMT sampling and petrophysical evaluation of wire line logs. The well was not tested due to the limited oil column present at the well location. One core was cut in the interval 2396 - 2408 m in the Heimdal Formation. An FMT segregated sample containing gas, oil, and mud filtrate was taken at 2398.4 m.\r\n\u003cbr\u003e\r\n\u003cbr\u003e\r\nThe well was permanently plugged and abandoned as an oil discovery\r\n\u003c/p\u003e\r\n\u003cb\u003e\r\nTesting\r\n\u003c/b\u003e\r\n\u003cp\u003e\r\nNo drill stem test was performed.\r\n\u003c/p\u003e\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"949","properties":{"OBJECTID":949,"wlbNpdidWellbore":2828,"wlbName":"9/2-A-4","wlbHistory":"\r\n\r\n\u003cp\u003eWell \u003ca name=\"OLE_LINK2\"\u003e\u003c/a\u003e\u003ca\r\nname=\"OLE_LINK1\"\u003e9/2-A-4 \u003c/a\u003eis a development well on the Yme Field in the\r\nNorwegian Danish Basin. It was the third Sandnes Formation oil producer drilled\r\non the Yme Gamma Vest structure.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 9/2-A-4 was spudded and drilled from\r\nslot 4 of the Yme template. The A-4 well was planned with an "S"\r\nshaped profile, in order to drill vertically through the upper Sandnes\r\nFormation in the northerly crestal area of the Gamma Vest structure, to the\r\nnorth of the A-4 slot and well A-8T2. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe Sandnes S12 target was penetrated at\r\n4630.5 m (3162.8 m TVD RKB), approximately 2887.6 m north of the platform, at\r\nan inclination of 17.8 deg. It was oil-filled down to the OWC at 4720 m (3252 m\r\nTVD RKB). The well was drilled to TD at 4845 m (3377 m TVD RKB) in the Bryne\r\nFormation.\u003c/p\u003e\r\n\r\n\u003cp\u003eA total of 68 m cores were cut in three\r\ncores at 4635 to 4704.5 m in the Sandnes Formation.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eProduction\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was produced from the intervals\r\n4677.6 - 4679.2 m, 4667 - 4671.5 m, and 4643.9 - 4654.3 m in the in the Sandnes\r\nFormation.\u003c/p\u003e\r\n\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"950","properties":{"OBJECTID":950,"wlbNpdidWellbore":2829,"wlbName":"1/3-8","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 1/3-8 is located on the Hidra High\r\nin the North Sea. The primary objective was to test the Jurassic Upper Ula sand\r\npackage within the Kamskjell prospect. The secondary objective was a sand\r\npackage at the base of the Jurassic. Planned TD was tagging the Triassic or\r\nreaching 5085 meters TVD SS.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 1/3-8 was spudded with the 3\r\nlegs jack-up installation Transocean Nordic on 12 December 1996 and drilled to\r\nTD at 5199 m in the Triassic Smith Bank Formation. Two major unscheduled events\r\noccurred in the 12 1/4" section. First, the mud line hanger failed. A\r\ntotal of 16 days was required to repair this before drilling could be resumed.\r\nSecondly, and more serious, a 3.5 bbl kick was taken at 4529 m while drilling a\r\nlimestone interval in the Early Cretaceous Cromer Knoll Group. Based on the\r\nworst case scenario interpretation of the kick, there could be a large volume\r\nof hydrocarbons (estimated at up to 300 bbls) in the annulus between the kick\r\nand thief zones. For this reason it was decided to rig up flare booms to\r\nincrease the rig safety should it become necessary to by-pass the MGS whilst\r\ncirculating out the influx. The well was opened up, and the influx circulated\r\nout at 3.3 bpm. Initially returns were taken through the MGS. After pumping\r\n1464 bbls returns were switched from the MGS to the boom. This decision was\r\ntaken as gas levels in the pit room were rising, and the seal leg pressure was\r\ndropping steadily (from 11.5 to 6.4 psi) indicating the onset of possible\r\nblow-down. The flare lit immediately with the clear burn characteristic of\r\ncondensate. A total of 420 bbls was flared before mud was at surface and the\r\nflare extinguished. A total of 15 days were spent stabilising the well to\r\npermit running casing and continue drilling the next sect","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"951","properties":{"OBJECTID":951,"wlbNpdidWellbore":2830,"wlbName":"33/9-19 S","wlbHistory":"\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 33/9-19 S is situated in the Tampen\r\nSpur area. The well targeted the Statfjord Nord Nordøst Segment at the\r\nnorth-eastern extension of the Statfjord North Field structure in blocks 33/9\r\nand 34/7. The objective was to prove the minimum economical recoverable\r\nreserves and the most likely oil water contact in the Brent Group.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe 33/9-19 S well was spudded on the 29\r\nof June 1996, using the semi-submersible installation "Transocean\r\nWildcat". The well was drilled in a north-western direction to TD at 3197\r\nm in the Early Jurassic Statfjord Formation. A pilot hole was drilled to 450 m.\r\nNo shallow gas was recorded. The 36" and 17 1/2" sections were\r\ndrilled with sea water and swept clean with bentonite mud. The 12 1/4"\r\nhole section was drilled with Ancho-2000 mud and the 8 1/2" hole section\r\nwas drilled with Ancovert Oil based mud. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe target Base Cretaceous/Top Brent was\r\nreached at 2689.0 m (2646.8 m TVD RKB), 28 m shallower than prognosed. Sandstone\r\nin the Brent Group was oil filled from top down to claystone at 2811 m. Drilling\r\ncontinued towards the planned TD in Dunlin Group with an inclination of 35°.\r\nAfter having reached this TD, it was decided to continue drilling in order to\r\ninvestigate the Statfjord Formation reservoir characteristics and to improve\r\nthe mapping of the Brent and Dunlin Groups. The inclination stayed at approximately\r\n29.5° to final TD at 3197 m (3061.5 m TVD RKB). Top Statfjord Formation, which\r\nwas water wet, came in at 3122 m (2996 m TVD RKB), 19 m TVD shallower than\r\nprognosed.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eOne 90 ft core was cut from 2709 to 2727\r\nm (100% recovery). The core jammed off after 18 m during coring of a calcite\r\ncemented san","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"952","properties":{"OBJECTID":952,"wlbNpdidWellbore":2847,"wlbName":"36/4-1","wlbHistory":"\r\n\r\n\u003cp\u003eWell \u003ca name=\"OLE_LINK2\"\u003e\u003c/a\u003e\u003ca\r\nname=\"OLE_LINK1\"\u003e36/4-1 \u003c/a\u003eis located in the Sogn Graben, ca 18 km south-east\r\nof the Agat field and ca 60 km west-northwest of Florø town in western Norway. The objective was to establish the presence, quality and fluid content of Jurassic\r\ntarget horizons (Fensfjord, Krossfjord, Sognefjord Formations and Brent/Dunlin\r\nGroups). The overlying Cretaceous sand of Late Cenomanian/Early Turonian age\r\n(k68) provided a secondary target. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 36/4-1 was spudded with the\r\nsemi-submersible installation Mærsk Jutlander on 3 September 1996 and drilled\r\nto TD in basement rock. Minor delays in the operations were caused by ROV\r\nproblems during spud and top hole drilling, and BOP problems while setting the\r\n13 3/8" casing at 1108 m. The well was drilled with sea water and gel down\r\nto 1108 m and with KCl/Polymer/GEM (Glycol Enhanced Mud) from 1108 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe Jurassic was encountered at 2361 m\r\nand consisted of 351 m of Heather Formation overlying Basement rock. No primary\r\nreservoir was penetrated only low porosity thin sands were encountered with no\r\nshows. Wire line logging and sampling confirmed absence of Jurassic reservoir\r\nin the 36/4-1 prospect. The secondary target was penetrated 38 m high to\r\nprognosis and contained 77 m of sand. This sand showed no indications of\r\nhydrocarbons and was at hydrostatic pressure. Dull hydrocarbon shows were\r\nobserved in sandstone stringers in the interval 1920-1990 m within the\r\nCretaceous Kyrre Formation. No shows were encountered in the remaining part of the\r\nwell. The failure of the primary target was attributed to lack of reservoir\r\nwithin the prospect. The secondary target probably failed due to lack of trap.\r\nHydrostatic pressure within this sand indicated connection up-dip to the shelf\r\nand hence no up-dip seal. Apart from the Heather Formation with TOC in the\r\nrange 1.5 to 4.3% and average HI of 340 mg HC/g TOC, no significant source rock\r\nformations were en","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"953","properties":{"OBJECTID":953,"wlbNpdidWellbore":2849,"wlbName":"6406/2-3","wlbHistory":"\u003cb\u003e\r\nGeneral\r\n\u003c/b\u003e\r\n\u003cp\u003e\r\nThe main objective of well 6406/2-3 was to test the hydrocarbon potential of the Kristin structure with respect to Middle and Lower Jurassic sandstones, and to test the reservoir qualities at great depths (prognosed TD 5600 m). The secondary target for the well was the seismically prognosed Aptian sandstone, which was interpreted to form either a stratigraphic trap or a structural closure above the crest of the Kristin structure. The Kristin structure is a fault bounded horst block, somewhat eroded in the western part, with only minor internal faulting. The Kristin structure extends into PL 134 area, and the well location was agreed between PL 199 and PL 134. PL 134 contributed with 20% of the expenses to the joint well. Hydrocarbon leakage due to the prognosed high pore pressure in the Kristin structure was regarded the primary risk for the trap, knowing that all high pressured wells drilled in this area had been dry.\r\n\u003c/p\u003e\r\n\u003cb\u003e\r\nOperations and results\r\n\u003c/b\u003e\r\n\u003cp\u003e\r\nWildcat well 6406/2-3 was spudded 24 August 1996 with the semi-submersible rig \"Transocean Arctic\", and reached TD 47 m into the Åre Formation at 5258 m on 26 January 1997. Due to well control problems starting 23 September a technical side-track was started 23 October from the 13 3/8\" casing shoe at 2834 m, and the suffix T2 was added to the well designation (6406/2-3T2). During intermediate logging in 8 1/2\" section a FMT tool got stuck, and a second sidetrack had to be done from the 9 5/8\" casing shoe at 4538 m. The second sidetrack, 6406/2-3T3, was started 6 December 1996.  Shallow gas caused no operational problems. The well was drilled with seawater swept with high viscosity mud down to 1413 m. ANCO 2000 water based mud with ANCO 208 glycol additive was used from 1413 to 2848 m, while ANCOVERT oil based mud was used from 2848 m to TD.\r\n\u003cbr\u003e\r\n\u003cbr\u003e\r\nThe main result of well 6406/2-3 was the discovery of gas/condensate in Garn and Ile Formations as proven by production tests, fluid samples, cores and logs. Both Garn and Ile F","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"954","properties":{"OBJECTID":954,"wlbNpdidWellbore":2863,"wlbName":"34/7-25 S","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 34/7-25 S is located near the\r\nsouthern extension of the Tordis field and North of the Gullfaks field in the\r\nTampen area in the Northern North Sea. The main objective of the well was to\r\ntest the presence of sand and hydrocarbon in a Late Jurassic prospect (the\r\nSouthern Triangle Upper Jurassic (STUJ) prospect). The STUJ prospect was\r\ndefined between Base Cretaceous Unconformity (BCU) and a Base Draupne\r\nreflector. Secondary objectives were to obtain pressure measurements in the Brent\r\nGroup, test presence of sand and hydrocarbons in the Cretaceous and in the\r\nPaleocene and prove migration route.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 34/7-25 S was spudded with the semi-submersible\r\ninstallation Deepsea Bergen on 31 July 1996 and drilled to TD at 3235 m (2596 m\r\nTVD) in the Early Jurassic Drake Formation. No significant problems occurred\r\nduring operations. The well was drilled with spud mud down to 1271 m and with\r\noil based mud (Anco Vert) from 1271 m to TD. No shallow gas was encountered.\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 34/7-25 S penetrated several sands in\r\nthe interval from 1250 m to 1700 m within the Hordaland Group. Weak shows were\r\ndescribed in the interval 2275 to 2295 m in the Lista Formation. The shows had\r\nno odour and no stain in the description, due to oil based mud. The Cretaceous\r\nsection had only traces of thin sandstone beds in the Shetland Group. The well successfully\r\nencountered 27.5 m TVD oil bearing sandstones belonging to the Draupne\r\nFormation, with top at 2791 m (2193 m TVD). No OWC was proven. The uppermost 2\r\nm was cemented and had the same log response as the limestone of the Cromer\r\nKnoll Group. The next 21 m (2195 - 2216 TVD) showed excellent reservoir\r\nproperties with porosity around 30% and permeability between 6 and 7 Darcy. This\r\nupper massive sandstone was bioturbated and showed a coarsening up character. The\r\nlower part of the Draupne Formation comprised sandstones interbedded with more\r\nsilty parts. This part of the formation had a very high g","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"955","properties":{"OBJECTID":955,"wlbNpdidWellbore":2866,"wlbName":"34/11-3","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eAppraisal well 34/11-3 was drilled on the\r\n34/11-1 Kvitebj ørn Discovery in the Northern North Sea. The primary objective\r\nwas to confirm hydrocarbon reserves in the Brent Group in this discovery.\r\nSecondary objective was to test the Early Jurassic Statfjord and Cook\r\nFormations. A third objective was to investigate properties of the Lista\r\nFormation of the Rogaland Group, which had significant shows in 34/11-1.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 34/11-3 was spudded with the\r\nsemi-submersible installation Deepsea Trym on 1 August 1996 and drilled to TD\r\nat 4482 m in the Early Jurassic Statfjord Formation. When drilling 8 1/2"\r\nhole at 4032 m a kick situation was experienced. A total of 23.8 days was spent\r\nbefore the operation could be continued. After drilling to TD problems occurred\r\nwith the BOP connector. A cement plug was set and the well suspended for\r\nrepairs of the connector. When drilling out the cement plug the well was\r\nunintentionally sidetracked at 4009 m. 34/11-3T2 was drilled to final TD at\r\n4230 m (4234 m loggers depth). The well was drilled with bentonite and seawater\r\ndown to 1115 m, with ANCO-2000 mud from 1115 m to 3985 m, and with ANCO THERM\r\nmud from 3985 m to TD (including sidetrack).\u003c/p\u003e\r\n\r\n\u003cp\u003eNo shows were observed in cuttings from\r\nthe Rogaland Group, but in core 1 thin sandstone laminae with weak shows were\r\nobserved. The top of the Brent Group was penetrated 14.5 m shallower than\r\nprognosed, and was proven to be gas/condensate bearing down to 4196.2 m. No GWC\r\nwas found. No visual shows were observed in the Cook Formation.\u003c/p\u003e\r\n\r\n\u003cp\u003eIn the Statfjord Formation, weak shows\r\nwere seen, and a weak HC odour from the core was noted.\u003c/p\u003e\r\n\r\n\u003cp\u003eAll conventional cores were cut in the\r\noriginal hole while all reservoir logging was performed in the sidetrack. Only\r\nMWD logs exist from the lower part of the original hole. A total of 101.8 m\r\nconventional core was recovered in 12 cores. Core 1 was cut from 2027 m to\r\n2035.6 m in the Lista For","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"956","properties":{"OBJECTID":956,"wlbNpdidWellbore":2867,"wlbName":"9/2-6 S","wlbHistory":" \u003cb\u003e\r\n General\r\n \u003c/b\u003e\r\n \u003cp\u003e\r\n The deviated well 9/2-6 S is located on the Yme Gamma South East structure, and was drilled from slot 6 of the Yme template. The well was planned as an exploration well, being the first well drilled on the South East structure, but would be completed as an oil production well if commercial oil reserves were proven, or sidetracked to the Yme Gamma Vest structure if the oil column was less than 25 m. The well objective was also to evaluate whether the Bryne Formation in this well could be used as an Yme gas injection well.\r\n \u003c/p\u003e\r\n \u003cb\u003e\r\n Operations and results\r\n \u003c/b\u003e\r\n \u003cp\u003e\r\n Wildcat well 9/2-6 S was spudded with the jack-up installation Mærsk Giant on 19 August 1996 and drilled to a total depth of 5205.0 m (3600.8 m TVD SS) in the Middle Jurassic Bryne Formation. The 9/2-6 S well was planned with a \"S\" shaped profile, in order to drill vertically through the Sandnes Formation in the crestal area of the Gamma South East structure, to the east of the graben separating the South East segment from the Yme Gamma Vest Field. However, due to difficulties dropping angle, a deviation to the plan was made so that the angle would be dropped to 30 deg. The well was drilled with seawater and gelled bentonite pills through the 37 &\" hole and with seawater and PAC pills through the 26\" hole down to 842 m. KCl/Aquadrill (with glycols) mud was used from 842 m to 2481 m, and with ester-based Petrofree mud from 2481 to TD. From 4845 m and to TD the well was drilled with Neyfor Turbine and diamond bit.\r\n The top of the Sandnes Formation reservoir was encountered al 4783 m (3228.7 m TVD SS), and the oil/water-contact was found at 3277.0 m TVD SS, giving an oil column of 48 m. The Sandnes S12 target was penetrated approximately 3085.5 m South East of the platform, at an inclination of 20.4 deg. 12 February 1997. Two cores were cut in the interval 4793 - 4845 m across the OWC in the Sandnes Formation. Core 2 (4808 - 4845 m) retrieved 40.8 m. The extra 3.8 m retrieved in this core is believed to be the lower ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"957","properties":{"OBJECTID":957,"wlbNpdidWellbore":2872,"wlbName":"33/9-19 A","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 33/9-19 A is situated in the Tampen Spur area. The well 33/9-19\r\nA was drilled to the Statfjord Nord Nordøst Segment (SFNNÏS) of the Statfjord\r\nField. This segment lies at the north-eastern extension of the Statfjord North\r\nField structure in both blocks 33/9 and 34/17. The primary objective for the\r\nwell 33/9-19 A was to identify the level of oil-water contact or a deep\r\n"oil-down-to-situation" within the Nord Nordøst Segment. The\r\nsecondary objective was to test the SFNNÏS Brent prospect on the north-western\r\nside of the Nordøst Segment main fault. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well 33/9-19A was spudded on the 23 of July 1996,\r\nusing the semi-submersible installation "Transocean Wildcat". The\r\nwell 33/9-19 A was sidetracked from well 33/9-19 S in a north- north-western\r\ndirection. Well 33/9-19 A was drilled from kick off at 2000 m to TD in the\r\nLower Jurassic Dunlin Group at 3514 m (3057.1 m TVD RKB). The section from 2000\r\n- 3514\r\nm (1999.9 - 3057.0 m TVD RKB)\r\nwas drilled in one bit run with Ancovert Oil based mud. \u003c/p\u003e\r\n\r\n\u003cp\u003eRepeated overpull and short stuck events made the logging-run\r\noperations difficult. Reservoir characteristics were similar to the Statfjord\r\nNord Field. The oil-water contact was in the Rannoch Formation at approximately\r\n2942 m (2735 m TVD RKB). The Brent Group sands were not encountered northwest\r\nof the main fault. TD was at 3514 m (3032 m TVD RKB) in the Dunlin Group. No\r\nfluid samples were collected and no coring was performed in the well.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently plugged and abandoned as an oil appraisal\r\nwell on 9 August 1996.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was performed\u003c/p\u003e\r\n\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"958","properties":{"OBJECTID":958,"wlbNpdidWellbore":2873,"wlbName":"33/6-2","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThe 33/6-2 well is\r\nlocated to the north of the Statfjord Nord oil field and to Northwest of Snorre\r\noil field. Agip's 33/6-1 well, which was plugged and abandoned dry, was drilled\r\napproximately 4 km to the west. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe primary objective\r\nof the well was the Upper Jurassic (Volgian) Intra-Draupne "Munin\r\nsandstone unit" of the Draupne Formation. It was designed to find\r\ncommercial hydrocarbons in a structural/stratigraphic trap where the Base Munin\r\nsub crops the base Cretaceous unconformity. The secondary objective of the well\r\nwas to test the reserve potential in the Brent Group, intra Dunlin Group and\r\nStatfjord Formation sandstones.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eExploration well\r\n33/6-2 was spudded with the semi-submersible installation "Byford\r\nDolphin" on 28 October 1996 and drilled to TD at 3950 m in the Early\r\nJurassic Statfjord Formation. The well was drilled with seawater and hi-vis\r\npills down to 991 m, with KCl/glycol ("ANCO 208") mud from 991 m to\r\n2150 m, and with KCl/polymer/glycol ("ANCO 208") from 2150 m to TD.\r\nIn the Upper Jurassic two cores were cut in sandstones of the Intra-Draupne\r\nsandstone unit. Whilst there were some shows, the sandstones proved to be\r\ngenerally low porosity. In the Early - Middle Jurassic Brent and Dunlin Group\r\nsandstones no oil shows were observed and no cores were taken. Weak shows were\r\nhowever observed in shaley/carbonaceous lithologies in this interval,\r\nindicating some in-situ generated hydrocarbons. No shows were observed in the\r\nStatfjord Formation. RFT fluid samples were retrieved from 3550 m in the\r\nIntra-Draupne Sandstone and from 3622 m in the Brent Group. By adding\r\nthiocyanate to the mud as a tracer it could be established that both samples\r\nwere heavily contaminated by mud (70 % ? 80 %).\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was plugged\r\nand abandoned as a dry hole with shows on 2 January 1997.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test\r\nwas performed.\u003c/p\u003e\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"959","properties":{"OBJECTID":959,"wlbNpdidWellbore":2874,"wlbName":"6610/2-1 S","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 6610/2-1S is located in the\r\nNordland III area off shore Northern Norway. The main objective was to test the\r\nhydrocarbon potential in Middle and Early Jurassic Sandstones of the Fangst and\r\nBåt Groups.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 6610/2-1S was spudded with\r\nthe semi-submersible installation Byford Dolphin on 27 August 1996 and drilled\r\nto TD at 2673 m in the Triassic Red Beds. The hole was drilled vertical down to\r\n938 m and deviated from that point to TD, with deviation mostly around 24 - 26\r\ndeg. No significant problems were encountered in the operations. The well was\r\ndrilled with spud mud down to 946 m and with ANCO 2000 mud from 946 m to TD. \u003c/p\u003e\r\n\r\n\u003cp\u003eA Lysing Formation sandstone was\r\npenetrated from 2050 m to 2067 m. At 2067 m a large hiatus from the Early\r\nJurassic Pliensbachian to the Late Cretaceous Coniacian was encountered. The\r\nTilje Formation was mostly silt and mudstone, while the Åre Formation contained\r\nup to 50 m thick sandstone units. All potential reservoir sections in the well\r\nwere found water wet. The top sand in the Lysing Formation had shows. These\r\nwere recorded conventionally on cuttings and a core on the rig and confirmed by\r\nlater geochemical analyses on shore. The geochemical analyses also detected\r\nshows in the Tare, Tilje, and Åre Formations. The analyses also detected use of\r\nan oil-based additive in the mud below 2063 m. This was not reported in the mud\r\nprogramme. This additive, together with the polyethylene glycols of the ANCO\r\n2000 mud system, hampered interpretations of the geochemical data, particularly\r\nin sections with low levels of organic matter. However, it was established that\r\nthe well is immature all through to TD, and that the best source rock intervals\r\nin this well were the coals (and coaly shales) in the Jurassic Åre Formation.\r\nThe potential of Åre is for gas generation. The Tertiary Brygge and Tang\r\nFormations also had a fair source potential for gas. \u003c/p\u003e\r\n\r\n\u003cp\u003eOne core was cut i","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"960","properties":{"OBJECTID":960,"wlbNpdidWellbore":2885,"wlbName":"2/6-5","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eBlock 2/6 is\r\nstructurally located on the eastern margin of the Norwegian part of the Feda\r\nGraben. The block partly covers the Piggvar Terrace, the metamorphic Mandal\r\nhigh and the northwestern part of the Søgne basin.\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 2/6-5 is\r\nlocated in the central western part of the block, high on a structural closure\r\ndefined on Top Shetland Group \u003c/p\u003e\r\n\r\n\u003cp\u003eThe main objective\r\nof well 2/6-5 was to test the presence of hydrocarbons and reservoir properties\r\nwithin the primary target intervals of the Shetland Group, located within a\r\nstructural closure above the northern part of the Mandal High. It was prognosed\r\napproximately 40 m below the distinct Late Cretaceous Top Ekofisk Formation\r\nreflector. \u003c/p\u003e\r\n\r\n\u003cp\u003eReservoir units were\r\nexpected in several intervals, some in pressure communication and some not. A\r\npossible secondary target of sediment fill in the interval between the Shetland\r\nGroup and the basement topography would be penetrated before reaching TD in\r\nmetamorphic rocks. However, this possible wedge was defined on a poor seismic\r\nresponse and could represent intra basement reflectivity. The well was planned\r\nas a possible future producer.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eExploration well\r\n2/6-5 was spudded by the semi-submersible installation "Deepsea\r\nBergen" 17 November 1996 and drilled to TD at 3260 m in metamorphic rocks.\r\nThe well was drilled with a sea water/bentonite mud system down through the 12\r\n1/2" hole section to 2515 m. The deeper part of the well was drilled with\r\na KCL polymer glycol mud system. \u003c/p\u003e\r\n\r\n\u003cp\u003eAbove the Shetland\r\nGroup the formation tops and lithologies were drilled within the uncertainty\r\nlimits of the prognosis. The Tertiary succession (including Quaternary) was\r\nfound to be 2872 m thick. The Nordland Group was 1404.7 m thick and consisted\r\nof clay/claystones and sands. Top of the Hordaland Group was encountered at\r\n1499.5 m and the Group was found to be 1229.4 m thick, generally consisting of\r\nreactive clay","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"961","properties":{"OBJECTID":961,"wlbNpdidWellbore":2886,"wlbName":"30/5-2","wlbHistory":"\r\n\r\n\u003cp\u003eWell 30/5-2 is located a few km west of\r\nthe Oseberg Field in the Northern North Sea. It was drilled on the northern and\r\ndown dip extension of the hydrocarbon accumulation discovered by well 30/8-1 S.\r\nThe main target was the Brent deltaic sands of the Tarbert Formations. The\r\nprimary objectives were to prove filling level and hydrocarbon types in a down\r\ndip (northern) direction, and to prove pressure communication and continuity\r\nwith the reservoirs in 30/8-1 S. Planned TD was 50 m into the Dunlin Group.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eAppraisal well 30/5-2 was spudded with\r\nthe semi-submersible installation Treasure Saga on 4 October 1996 and drilled\r\nto TD at 4076 m in the Early Jurassic Drake Formation. The total duration of\r\nthe well was some 20 days behind schedule. The main contribution to this was\r\ntime spent to cure a shallow gas source, corrective measures in conjunction\r\nwith a 13 3/8" casing hanger sitting high and a stuck MDT tool. The well\r\nwas drilled with spud mud and bentonite down to 1558 m, with KCl/polymer mud\r\nfrom 1558 m to TD. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThe main reservoir interval consisted of\r\nthe Tarbert Formation, but the Ness and ORE Formations were also encountered.\r\nGas and oil pay was interpreted below 3528.5 m in the "Tarbert 2"\r\nreservoir, approximately 58 m and 10 m respectively. The well interpretation\r\nconcludes with a GDT (gas down to) situation at 3591.5 m in the Tarbert 2\r\nreservoir and with an OUT (oil up to) at 3602 m. An OWC is indicated at 3614 m\r\nwith a FWL (free water level) at about 3616.5 m. In the Ness Formation a total\r\nof 16 m pay was interpreted in channel sands. The assumed fluid in these sands\r\nis gas, but this was not conclusively proven. The ORE (Oseberg - Rannoch -\r\nEtive) Formation had 1.4 m pay interpreted, but this may be an optimistic\r\nresult as it was equally likely that this could represent so-called residual\r\nhydrocarbons. The reservoir properties are considered fairly modest with\r\nporosities generally bel","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"962","properties":{"OBJECTID":962,"wlbNpdidWellbore":2891,"wlbName":"3/7-6","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 3/7-6 is located ca 4 km\r\neast-northeast of the Trym Field close to the boarder to Denmark. The objective\r\nwas to test the hydrocarbon potential of the Farsund Formation sandstones in\r\nthe "Spekkhugger" prospect, a stratigraphic trap.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 3/7-6 was spudded with the\r\nsemi-submersible installation Mærsk Jutlander on 8 October 1996 and drilled to\r\nTD at 4120 m in the Late Jurassic Haugesund Formation. The hole was drilled\r\nwith less than 2 deg deviation down to 3370 m where deviation suddenly\r\nincreased to around 10 deg with a maximum of 13.3 deg at 3750 m. Otherwise the\r\nwell was drilled without significant technical problems. The mud used was\r\nseawater/spud mud down to 1105 m, Barasilc (sodium silicate) mud from 1105 m to\r\n3425 m, and KCl/polymer mud from 3425 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well encountered the top Jurassic,\r\nFarsund Formation at 3439 m and the underlying Haugesund Formation at 4050 m.\r\nFour units of sandstones with good porosities were encountered between 3469 and\r\n4050 m in the Farsund Formation. Weak to moderate hydrocarbon shows were\r\nobserved in ditch cuttings and on core samples between 3621 and 4030 m, but the\r\nformations were evaluated as water bearing.\u003c/p\u003e\r\n\r\n\u003cp\u003eA 10.4 metre spot core was recovered from\r\n3640 to 3650.44 m. Three segregated MDT samples were taken at 3478 m. They\r\ncontained water with traces of gas.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was plugged and permanently\r\nabandoned on 30 November 1996 as a dry hole with shows.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was performed.\u003c/p\u003e\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"963","properties":{"OBJECTID":963,"wlbNpdidWellbore":2918,"wlbName":"32/4-1","wlbHistory":"\u003cb\u003e\r\nGeneral\r\n\u003c/b\u003e\r\n\u003cp\u003e\r\nWildcat well 32/4-1 was the first well drilled in Production Licence 205. It is located on the Horda Platform in the Northern North Sea about five kilometers east of the East Troll Gas Field. The primary objective of the well was to prove commercial reserves within the Upper Jurassic Sognefjord Formation sand reservoirs. The Alpha prospect was believed to be filled with oil spilled from the Troll Field. Secondary objectives were present in potential stacked Upper, Middle and Lower Jurassic sand reservoirs, in Triassic, and in possible Paleozoic sand reservoirs.\r\n\u003c/p\u003e\r\n\u003cb\u003e\r\nOperations and results\r\n\u003c/b\u003e\r\n\u003cp\u003e\r\nWell 32/4-1 was spudded 21 October 1996, using the semi-submersible drilling rig \"Transocean 8\". The first attempt to drill the well failed after experiencing problems when running the 13 3/8\" casing. The casing unscrewed and parted at 619 m. The hole was filled with cement and abandoned. The rig was moved about 50 m to the north and the well was respudded. The well was drilled without major drilling problems, except for some difficulties with getting the 9 5/8\" casing hanger through the BOP stack and mud losses when drilling through the Viking Group. The well was drilled into Basement rocks at a total depth of 3186 m. The well was drilled with spud mud to 720 m and water based KCl/Drispac with glycol from 720 m to TD.\r\n\u003cbr\u003e\r\n\u003cbr\u003e\r\nThe Upper Jurassic reservoir interval was encountered 6 m shallower than prognosed and contained 65.5 m of water-wet Sognefjord sandstones. In addition, water wet sandstones of the secondary targets were present as the Fensfjord, Krossfjord, Cook, Statfjord and Lunde Formations.\r\n\u003cbr\u003e\r\n\u003cbr\u003e\r\nFour cores were cut in the Upper Jurassic. The two first were cut in the Heather Formation silt- and sandstones, while core 3 and 4 were cut in sandstones of the Sognefjord Formation (1220-1235.5 m, 1232.5-1237.5 m, 1237.5-1256 m and 1257-1275 m, respectively). A FMT water sample was collected from 1359 m.\r\n\u003cbr\u003e\r\n\u003cbr\u003e\r\nThe well was permanently plugged and abandoned as a ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"964","properties":{"OBJECTID":964,"wlbNpdidWellbore":2931,"wlbName":"34/4-9 S","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 34/4-9 S was drilled on the northern\r\npart of the Western Central Fault Block (WCFB) on the Snorre Field in the\r\nnorthern North Sea. This is an appraisal well and the main objectives were to contribute\r\nto the technical basis for Snorre North PDO and to reduce the uncertainties in\r\nreservoir quality. The reservoir level in this part of Snorre is the Late\r\nTriassic Lunde Formation.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eAppraisal well 34/4-9 S was spudded with\r\nthe semi-submersible installation Scarabeo 5 on 8 January 1997 and drilled to\r\nTD at 3440 m (3388 m TVD) in the Late Triassic Lunde Formation. The well was\r\ndrilled vertical down to 2700 m, from where it built angle up to 24.9 deg at TD\r\nwith maximum 29.6 deg at 3370 m. The well was drilled with spud mud down to\r\n1235 m, with KCl mud from 1235 m to 1866 m, and with Ancovert oil based mud\r\nfrom 1866 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eTop of the reservoir ( L01) was\r\nencountered at 2512.5 m, 12.5 m deeper than prognosed. The conventional core\r\nindicated oil down to 2621.5 m (2596 m TVD MSL) (oil stained sandstones), and\r\nthe interpretation of pressure gradients (MDT data) indicate an OWC at 2619 m (2594\r\nm TVD MSL). However, the wire line logs indicate high water saturation in the\r\nsandstone from 2616.5 - 2622 m (2590.5 - 2597 m TVD MSL) with deepest oil down\r\nto 2608 m (2583m TVD MSL). The oil-water contact is therefore set to 2616 m (2590\r\nm TVD MSL). \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThree cores were cut consecutively over a\r\n209 m long section from 2515 m to 2724 m in the upper part of the Lunde formation\r\nwith a total recovery of 99.7 %. The core-to-log shifts were -0.61 m for core\r\n1, -1.11 m for core 2, and -0.36 m for core 3. A 2 3/4 gal fluid sample was\r\nobtained at 2583 m. Laboratory measurements ind","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"965","properties":{"OBJECTID":965,"wlbNpdidWellbore":2932,"wlbName":"6610/3-1 R2","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 6610/3-1 is located ca 80 km\r\nsouthwest of the Røst Island in the Lofoten archipelago of Northern Norway. The\r\nobjective of re-entry 6610/3-1R2 was plug and abandonment.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 6610/3-1R was re-entered\r\nwith the semi-submersible installation Byford Dolphin on 1 October 1996. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was plugged and permanently\r\nabandoned on 7 October 1996 as a dry hole with shows\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was performed.\u003c/p\u003e\r\n\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"966","properties":{"OBJECTID":966,"wlbNpdidWellbore":2952,"wlbName":"6204/10-2","wlbHistory":"\u003cb\u003e\r\nGeneral\r\n\u003c/b\u003e\r\n\u003cp\u003e\r\nThe main objectives for well 6204/10-2 was to prove economic hydrocarbon reserves in the Jurassic\r\n L-prospect and in the Coniacian/Turonian Q-prospect, while secondary objective was to investigate\r\npossible hydrocarbons in fractured basement.\r\n\u003c/p\u003e\r\n\u003cb\u003e\r\nOperations and results\r\n\u003c/b\u003e\r\n\u003cp\u003e\r\nThe 6204/10-2 well was spudded with the semi-submersible rig \"Deepsea Trym\" on 19 January\r\n1997 and drilled to a temporary TD at 1145 m, where the well was temporarily abandoned on 21 november due to\r\nenvironmental restrictions. Well 6204/10-2 R was re-entered on\r\n4 November 1997, and was drilled to TD at 2095 m.\r\nThe well bores were drilled with a water based KCl polymer system, however,\r\nstandard geochemical analyses indicate unknown additives that may affect geochemical analyses.\r\nNo special drilling/operational problems were experienced in this well.\r\n\u003cbr\u003e\r\nThe well showed that the Jurassic section was missing, and there were no hydrocarbons in the basement.\r\nThe only hydrocarbons encountered were in a thin Lower Cretaceous sandstone stringer,\r\nwhere a segregated FMT sample at 1915.5 m gave a good sample from a porous sandstone.\r\nTwo cores were cut: one at 1872 - 1889.55 m in Upper Cretaceous and one at 1951 - 1961.14 m\r\nin Lower Cretaceous. The well was plugged and abandoned on 21 November 1997 as a gas discovery.\r\n\u003c/p\u003e\r\n\u003cb\u003e\r\nTesting\r\n\u003c/b\u003e\r\n\u003cp\u003e\r\nNo drill stem test was performed.\r\n\u003c/p\u003e\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"967","properties":{"OBJECTID":967,"wlbNpdidWellbore":2954,"wlbName":"6507/3-2","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 6507/3-2 was\r\ndrilled in the Nordland III area, east of the Skarv Field. The main objective\r\nwas to test the hydrocarbon potential in the Middle and Lower Jurassic\r\nSandstones of the Fangst and Båt Groups.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\u003cp\u003eExploration well 6507/3-2 was spudded with the semi-submersible installation \"Transocean 8\" on 6 April 1997 \r\nand drilled to a total depth of 2032 m in the Triassic Red Beds. \r\nThe well was drilled with seawater and hi-vis pills down to 1000 m and with Staplex / KCl / Polymer mud from 1000 m \r\nto TD. One run with the Western Atlas FMT tool was performed. Two conventional cores were cut. One was cut in \r\nthe interval 1230 m to 1236 m in the Tilje Formation; the other was cut in the interval 1402 m to 1413 m in\r\n the Åre Formation. One sample containing gas was collected at 1206.5 m in the uppermost Fangst Group. \r\n The 10-litre chamber was emptied offshore. Analysis showed a dry, most likely biogenic gas,\r\n  containing mainly C1 (97.3%), some C2 (2.3%) and traces of C3 (0.4%). The well was plugged and abandoned \r\n  27 April 1997 as a dry well.\u003c/p\u003e\r\n\r\n\r\n\r\n\r\n\u003cp\u003e\u003cb\u003eTesting \u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test\r\nwas performed. \u003c/p\u003e\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"968","properties":{"OBJECTID":968,"wlbNpdidWellbore":2955,"wlbName":"25/10-8","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 25/10-8 was drilled with \"Deep Sea\r\nTrym\" to test the Hanz prospect with multiple targets. The well found gas and\r\noil in the Upper Jurassic. A sidetrack, 25/10-8 A, was drilled to test the\r\nextension of this discovery to the east. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eExploration well 25/10-8 was spudded with\r\nthe semi-submersible installation \"Deepsea Trym\" 17 February 1997 and drilled to a total depth of 2653 m in the\r\nEarly Permian Rotliegend Group. Water based mud was used down to 1080 m and an\r\nAncoVert oil based mud from 1080 to TD. Well 25/10-8 found the Heimdal Fm to be\r\nwater wet, the Upper Jurassic sands to contain gas and oil and the Middle\r\nJurassic and Rotliegendes sands to be water wet. A core was cut from 2080 -\r\n2107 m in the Heimdal Formation, a second core was cut from 2518 - 2546 m in\r\nCallovian Jurassic to Triassic sediments. After testing the well was plugged\r\nback to the 13 3/8" casing on 4 April 1997 as an oil and gas\r\ndiscovery. Sidetrack 25/10-8 A was\r\nkicked off from 1067 m and drilled to a total depth of 3460 m (2537 m TVD RKB)\r\nin Late Jurassic. An 8 1/2" hole was drilled to core point at 3110 m using\r\noil based mud. Three cores were cut in the Late Jurassic; 3110 to 3147 m, 3147\r\nto 3165 m , and 3165 to 3202 m. No wireline logs were run in well 25/10-8 A,\r\nonly MWD. No fluid samples were taken. All reservoir sands were found water wet\r\nand sidetrack 25/10-8 A was permanently abandoned as a dry well on 27 April\r\n1997.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 25/10-8 was perforated from 2391.4 -\r\n2398.4 m in the Upper Jurassic. The drill stem test flowed 692 Sm3/D oil of\r\ndensity 0.84 g/cm3\u003c/p\u003e\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"969","properties":{"OBJECTID":969,"wlbNpdidWellbore":2974,"wlbName":"6608/8-1","wlbHistory":"\u003cb\u003e\r\nGeneral\r\n\u003c/b\u003e\r\n\u003cp\u003e\r\nThe main objective for the well was to test the hydrocarbon potential in the Permian carbonates, which was an unproven play type in this area. Secondary objectives were to test possible Pliocene Kai Formation sandstone near the prognosed pinch-out, possible Paleocene sandstone, Triassic sandstones, and Permian sandstone/weathered basement.\r\n\u003c/p\u003e\r\n\u003cb\u003e\r\nOperations and results\r\n\u003c/b\u003e\r\n\u003cp\u003e\r\nThe well was drilled vertically using a water based mud to 3013 m RKB where massive losses occurred. It was not possible to stabilize the well, and it was plugged back permanently. \r\nThe well was classified as a dry well. Traces of oil shows were however reported during drilling in the uppermost part of the Triassic succession. High gas readings that probably originated from TD were recorded during circulation to stabilize the well. Two cores were cut from 1833 to 1843 m RKB in Triassic and another two from 2766 to 2795 m in Permian. An FMT fluid sample from 1832 m RKB contained mainly mud filtrate and only trace hydrocarbon gases.\r\n\u003c/p\u003e\r\n\u003cb\u003e\r\nTesting\r\n\u003c/b\u003e\r\n\u003cp\u003e\r\nNo drill stem test was performed\r\n\u003c/p\u003e\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"970","properties":{"OBJECTID":970,"wlbNpdidWellbore":2977,"wlbName":"6506/12-11 SR","wlbHistory":"\u003cb\u003e\r\nGeneral\r\n\u003c/b\u003e\r\n\u003cp\u003e\r\nThe well 6506/12-11 S was planned to be completed as a future producer. The main objectives of the well were to collect data on reservoir quality and fluid distribution, perform a long-term test to evaluate the continuity of the reservoir in the Tilje Formation, carry out an interference test between this well and an adjacent gas injector, 6506/11-5 S, and to investigate the effect of stimulation by fracturing on well productivity.\r\n\u003c/p\u003e\r\n\u003cb\u003e\r\nOperations and results\r\n\u003c/b\u003e\r\n\u003cp\u003e\r\nThe deviated appraisal well 6506/12-11 S was spudded on 8 June 1996 with the semi-submersible installation \"Transocean Searcher\" and drilled to a TD of 5268 m (4842.5 m TVD), approximately 60 m into the Åre Formation. Drilling was interrupted for 11 days by a labour conflict. The well was drilled with seawater and high viscosity pills down to 621 m, Anco 2000 mud with glycol from 621 to 2242 m, and with oil based Anco vert from 2242 m to TD.\r\nThe well penetrated the top of the Tilje Formation and the Åre Formation, respectively, 18 m and 9.5 m shallower than prognosed. Both the Tilje and the Åre Formations were hydrocarbon bearing. Two tests were performed, one in Åre and one in Tilje. In addition, a minifrac test was performed in the Åre Formation. Six cores (196 m, 187 m recovered) were cut in the Tilje and Åre Formations. Three MDT wireline samples were taken in the well, one from each of the formations Åre, Tilje, and Garn. The samples from the Tilje and Åre Formations contained oil and gas, while the sample from the Garn Formation, contained formation water.\r\nA 7\" liner was run and cemented on 9 August 1996.  \r\nAfter testing, well 6506/12-11 S was suspended on 7 September 1996 as an oil appraisal well. The well was re-entered (6506/12-11 SR) on 11 November 1996 for an extended test. Well 6506/12-11 SR was suspended as an oil appraisal well on 1 February 1997 and re-classed to development well 6506/12-I-4 H.\r\n\u003c/p\u003e\r\n\u003cb\u003e\r\nTesting\r\n\u003c/b\u003e\r\n\u003cp\u003e \r\nTest 1 in 6506/12-11 S was carried out over the interval 5226 - 5235.5 ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"971","properties":{"OBJECTID":971,"wlbNpdidWellbore":2986,"wlbName":"30/11-5","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 30/11-5 is located in the Viking\r\nGraben in the North Sea, between the Oseberg Field area and the Frigg Field\r\narea. The objective of the well was to test the presence of hydrocarbons in\r\nMiddle Jurassic Brent Group sandstones in the "Steinbit" prospect, a\r\nfault-dependent structure in Block 30/11. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 30/11-5 was spudded with the\r\nsemi-submersible installation Maersk Jutlander on 5 December 1996 and drilled\r\nto TD at 3726 m in the Early Jurassic Drake Formation. A boulder bed in the top\r\nhole from 160 m to 180 m caused some difficulties with entering the 30"\r\nsurface conductor casing. The GST (geosteering motor with resistivity at the\r\nbit) failed in the 8 1/2" section, and was substituted with a MWD/CDR\r\nconfigured in rotary mode to bring the resistivity sensor as close to the bit\r\nas possible. The well was drilled with seawater and bentonite hi-vis pills down\r\nto 1430 m, and with sodium silicate (Barasilc) mud from 1430 m to 3098 m. From\r\n3098 m to TD the Barasilc mud was gradually replaced with KCl/polymer mud. The\r\nBarasilc mud consists of soluble silicates and KCl/polymer based fluid.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well found the Middle Jurassic\r\nTarbert and Ness Formations within prognosis ranges, with good porosities. A\r\ntotal of 19.2 m net oil pay distributed in several thin intervals was\r\nencountered in the well, overlying water-bearing sandstones. Two OWC's were\r\nplaced at 3366 m and at 3432 m. Evaluation of the RFT data from well 30/11-5\r\nshows different reservoir pressures between the wells 30/11-5 and the wells\r\n30/11-3 and -4 to the south and 30/9-16 to the north. The pore pressures are\r\nalso different between the various Tarbert reservoirs within 30/11-5, although\r\nthe data remain in a hydrostatic pressure regime. \u003c/p\u003e\r\n\r\n\u003cp\u003eOil shows on cuttings were described as\r\nfollows: 3249 - 3310 m, on siltstone, limestone, and coal: weak blue white\r\nfluorescence with a slow white cut. Some mineral fluorescence ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"972","properties":{"OBJECTID":972,"wlbNpdidWellbore":2988,"wlbName":"25/8-9","wlbHistory":" \u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n \r\n \u003cp\u003eWell 25/8-9 is\r\n located East-Northeast of the Jotun Field. The two main objectives for drilling\r\n well 25/8-9 were to test the hydrocarbon potential of Early Palaeocene Heimdal\r\n Formation sandstones (Krap prospect) and secondly sandstones of the Middle\r\n Jurassic Hugin Formation. The well found oil in the Early Heimdal Formation and\r\n it was decided to sidetrack (25/8-9 A) to appraise and test the hydrocarbon\r\n potential in this discovery.\u003c/p\u003e\r\n \r\n \u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n \r\n \u003cp\u003eExploration well\r\n 25/8-9 was spudded with the semi-submersible installation "Byford\r\n Dolphin" on 5 January 1997 and drilled to TD at 2548 m in the Early\r\n Jurassic Amundsen Formation. The well was drilled with seawater and\r\n pre-hydrated bentonite sweeps down to 1110 m and with "Ancovert" oil\r\n based mud from 1110 m to TD. No shallow\r\n gas or boulder beds were encountered in the uppermost well section. Well 25/8-9\r\n penetrated mainly clays and claystones in the Nordland, Hordaland, and Rogaland\r\n groups with both the Utsira (694 m to 905 m) and Grid (1300.5 m to1345.0 m)\r\n Formation sandstones being present. Interbedded shales and thin Heimdal\r\n Formation sands were encountered between 2096 and 2189 m and hydrocarbons were\r\n found present in the uppermost reservoir section, however reservoir quality\r\n proved very poor. A FWL/OWC was not possible to define either from MDT\r\n (pressure) or logs, but an ODT at 2069 m TVD SS was established. Top Ty\r\n Formation was reached at 2228 m, consisting of upper clean sand divided by a\r\n shaly unit from a lower clean sandstone divided by a thin shale bed. It\r\n continued down to top Shetland Group at 2323 m. No hydrocarbons were found in\r\n the Ty Formation. The Shetland Group consisted mainly of chalk with the Cromer\r\n Knoll Group consisting of limestones interbedded with claystones and marls. \u003c/p\u003e\r\n \r\n \u003cp\u003eThe Hugin Formation\r\n sandstones came in at 2432 m and were found to be water bearing. One core\r\n totalling 27 metres was cut in the","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"973","properties":{"OBJECTID":973,"wlbNpdidWellbore":2989,"wlbName":"6608/8-2","wlbHistory":"\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003e \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe 6608/8-2 Bjørk well was drilled 6 km\r\nSouth/Southwest of 6608/8-1, 15 km Northeast of 6608/10-5, 22 km northeast of\r\n6608/10-1, 13 km Northwest of 6608/11-4 (Linerle) and 33 km Northeast of the\r\nNorne Field. It is located in the Norwegian Sea at the boundary between the Dønna\r\nTerrace and the Nordland ridge. The primary objective was to prove hydrocarbons\r\nin the Cretaceous (Coniacian) Lysing sandstones of the Cromer Knoll Group. \u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 6608/8-2 was spudded with the\r\nsemi-submersible installation Ocean Vanguard on 14 October 2007 and drilled to\r\nTD at 2831 m in the Late Triassic Red Beds. The well was drilled with seawater\r\ndown to 1507 m and Aquadrill mud from 1507 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoNormal\u003e\u003cspan lang=EN-GB\u003eThe well was dry without shows. Several thick reservoir\r\nzones were encountered in Cretaceous rocks and petrophysical analyses showed that\r\nthe Cromer Knoll section contained 79 m net sand with a porosity of 23 %.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo cores were cut and no wire line fluid\r\nsamples were taken.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe well was permanently abandoned on 29\r\nNovember 2007 as a dry well.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eTesting\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo drill stem test was performed.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"974","properties":{"OBJECTID":974,"wlbNpdidWellbore":2990,"wlbName":"36/7-2","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 36/7-2 was drilled on the Øygarden\r\nFault Complex, ca 14 km west of the outer skerries of Bulandet in Sogn og\r\nFjordane county. The primary target were the Late Jurassic Sognefjord and the Upper Jurassic Fensfjord formations.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 36/7-2 was spudded with the\r\nsemi-submersible installation West Vanguard on 2 September 1997 and drilled to\r\nTD at 1435 m in basement rock. An anchor test was performed after setting the\r\n13 3/8" casing shoe. Anchor no. 2 and 3 failed the test to 180 ton and\r\nslipped at 170 ton. Piggyback anchors were set on anchor no. 2, while main\r\nanchor no. 3 was lost. Fishing for the anchor chain was delayed 47.5 hrs due to\r\nbad weather. The anchor chain was retrieved and the anchor reset with two piggy\r\nbacks. Both anchors then stood a successful test. The well was drilled with\r\nseawater and hi-vis pills down to 591 m and with ANCO 2000 from 591 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well discovered heavily biodegraded\r\noil in the Middle Jurassic deltaic sandstone reservoir of the Fensfjord\r\nFormation. The overlying Sognefjord Formation sands were tight and contained no\r\nhydrocarbons. A 32.5 m oil column was proven from 931.5 to ca 964.0 m. The\r\nexact level of the oil-water contact could not be determined as it was in a\r\nshaley zone. Oil shows on cuttings were recorded from 915 m down to 1045 m. The\r\nreservoir zone of the Fensfjord Formation was divided into two units, from\r\nwhich only the upper had good reservoir properties. \u003c/p\u003e\r\n\r\n\u003cp\u003eNo conventional cores were cut, but 60\r\nsidewall cores were taken from 603 to 1408 m with a recovery of 56 samples. The\r\nMDT tool was run and 23 good pressure points were acquired in addition to a\r\nfluid sample at 934.5 m. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was completed on 22 September\r\n1997 as an oil discovery.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was performed.\u003c/p\u003e\r\n\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"975","properties":{"OBJECTID":975,"wlbNpdidWellbore":2993,"wlbName":"35/4-1","wlbHistory":"\u003cb\u003e\r\nGeneral\r\n\u003c/b\u003e\r\n\u003cp\u003e\r\nWell 35/4-1 was committed to test the hydrocarbon potential of Jurassic sandstones. The main target was the Brent Group. The Cook and Statfjord Formations were secondary targets. In addition the well should establish a good seismic tie. \r\n\u003c/p\u003e\r\n\u003cb\u003e\r\nOperations and results\r\n\u003c/b\u003e\r\n\u003cp\u003e\r\nWell 35/4-1 was spudded with the semi-submersible rig \"Treasure Saga\"on 24 December 1996 and reached TD on 30 April 1997 at a depth of 4936 m in the Triassic Hegre Group, fulfilling the objectives of the target depth. Including an expanded coring programme the activities lasted for 155 days, some 63 days behind the original budget. The main contribution for the budget overrun were bad weather conditions, technical problems in the well, technical problems for the drilling contractor, slow penetration rate in the lower sections section and a comprehensive plug and abandonment programme. The well was drilled water based to 3138 m (bentonite to 1362 m and ANCO 2000 mud from 1362 m to 3138 m) and oil based (ANCOVERT) from 3138 m to TD.\r\n\u003cbr\u003e\r\n\u003cbr\u003e\r\nThe well was found to be dry with weak hydrocarbon shows from the Eocene throughout the entire underlying section and into the Statfjord Formation. The well encountered sands within the Eocene, Dunlin Group and Statfjord Formation. The Brent Group, which was the primary target, contained mostly silts and very little sands of reservoir quality.\r\nHigh formation pressure was detected from the upper part of the Cretaceous to TD with a maximum of 1.84 rd recorded in the Brent Group.\r\n\u003cbr\u003e\r\n\u003cbr\u003e\r\nSeven cores were cut in the interval 4084 m to 4266 m in the Brent Group and two cores in the Lower Jurassic  (4447 m to 4475 m  and  4709 m to 4737 m). The well was plugged and abandoned as a well with shows.\r\n\u003cbr\u003e\r\n\u003c/p\u003e\r\n\u003cb\u003e\r\nTesting\r\n\u003c/b\u003e\r\n\u003cp\u003e\r\nNo drill stem test was performed.\r\n\u003c/p\u003e\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"976","properties":{"OBJECTID":976,"wlbNpdidWellbore":3008,"wlbName":"2/8-16 S","wlbHistory":"\r\n\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eValhall well 2/8-16 S was drilled from\r\nthe Valhall platform in the Southern North Sea. The objective was to evaluate\r\nthe Mjød structure in the Tor Formation on the eastern flank of the Valhall\r\nField.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 2/8-16 S was drilled in\r\ncombination with development well bores on the Valhall Field, using a down hole\r\nsplitter system (DHS) marketed by Baker Oil Tools and Kværner National. The\r\n2/8-16 S well was spudded from the "Splitter Housing" installed at ca\r\n1409 m and proceeded without too much trouble to 1662 m where mud losses were\r\nseen. At 1927 m the losses had become severe, and this had not been seen on\r\nValhall before. Examination of a seismic dip-map at approximately 1700 m TVD\r\nRKB showed that the well track had crossed a major fault at about the same\r\ndepth as the losses became severe. The seismic image indicated the zone could\r\nbe about 75 m wide. After curing the mud loss problems drilling continued to\r\n3139 m, where a wiper trip was made back to 2100 m. On running back in hole an\r\nobstruction was hit at 2133 m. After working past this obstruction it became\r\nevident that the hole had collapsed. At this time it was decided to abandon the\r\nwell track in favour of drilling an oil production well 2/8-A20 B. Well 2/8-16\r\nS was drilled using an oil-based mud.\u003c/p\u003e\r\n\r\n\u003cp\u003eAs the reservoir section was not reached,\r\nno log evaluation was done and the well was classified as a junk well.\u003c/p\u003e\r\n\r\n\u003cp\u003eNo cores were cut and no wire line fluid\r\nsamples taken.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 14\r\nMarch as a junk well.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was performed\u003c/p\u003e\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"977","properties":{"OBJECTID":977,"wlbNpdidWellbore":3009,"wlbName":"35/11-9","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 35/11-9 is located ca 14 km north of\r\nthe Troll Field and ca 3.5 km south-east well 35/11-8 S, which discovered oil\r\nand gas in a 79 m thick Intra Heather Sandstone unit, termed the "Early\r\nOxfordian Turbidite" sequence. Well 35/11-9 was designed to appraise the\r\noil and gas resources of this discovery. It should delineate the hydrocarbon\r\ncontacts and test the lateral continuity and cementation of the turbidite\r\nsequence. The Sognefjord Formation was seen as secondary objective.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eAppraisal well 35/11-9 was spudded with\r\nthe semi-submersible installation West Delta on 2 March 1997 and drilled to TD\r\nat 2830 m in the Late Jurassic Heather Formation. The well was drilled with\r\nseawater to 1250 m and with ANCO 2000 water based glycol mud from 1250 m to TD.\r\n\u003c/p\u003e\r\n\r\n\u003cp\u003eThe Intra Heather Sandstone unit was\r\nencountered at 2653 m. From 2653 m to 2688 m, 30 m net pay oil reservoir showed\r\noil saturation of 76% and the average porosity was calculated to 22.1%. MDT\r\npressure measurements gave an oil-water contact at 2687 m (2658 m TVD MSL),\r\nwhich is 4 m deeper than the oil-water contact in well 35/11-8 S. The top\r\nreservoir was, as prognosed, penetrated below the expected gas-oil contact for\r\nthe structure. However, the main conclusion is that within the range of\r\nuncertainties there are pressure communication both in the oil and the gas\r\nzones.\u003c/p\u003e\r\n\r\n\u003cp\u003eNo reservoir sand was encountered in the\r\nSognefjord Formation. No shows were reported above top Jurassic, and all shows\r\napart from those in the Intra Heather Sandstone reservoir, were found\r\nassociated with in-situ source rock shales . Organic geochemical analyses\r\nshowed that the oils from 35/11-8 S and 35/11-9 are very similar although a\r\nslightly lower maturity was noted for 35/11-8 S. Three conventional cores were\r\ncut from 16 m above the Intra Heather Sandstone to 8 m below the Heather\r\nSandstone. MDT fluid samples were taken at 2706 m (water), 2677.4 m (oil),\r\n2679.9 m (o","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"978","properties":{"OBJECTID":978,"wlbNpdidWellbore":3012,"wlbName":"6406/2-4 S","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eAppraisal well\r\n6406/2-4 S was drilled on the southern part of the Lavrans structure in the\r\neastern part of block 6406/2, south of the Smørbukk Field and west of the\r\nTrestakk Field on Haltenbanken. The Lavrans structure is a rotated fault block\r\nwest of the Trestakk Fault on the Halten Terrace. The purpose of the well was\r\nto appraise the southward extension of hydrocarbons in the Garn, Ile and Tofte\r\nFormations in the Lavrans structure, and to test separate closures in the Tilje\r\nand Åre formations. In addition, the well was planned to test the productivity\r\nimprovement achievable by hydraulic stimulation. The well should also penetrate\r\ntwo sandy zones of Turonian (Lysing Formation) and Cenomanian/Albian age (Intra\r\nLange sandstone).\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThe deviated\r\nappraisal well 6406/2-4 S was spudded 18 January1997 with the semi-submersible\r\ninstallation "Deepsea Bergen". It was drilled to 4546 m (4457 m TVD)\r\nin the Melke Formation. Mainly because of the weather conditions (41 days of\r\nWOW and weather-related problems) drilling of 6406/2-4 S was significantly\r\ndelayed. Due to environmental restrictions in the area the well had to be\r\nsuspended on April 5 1997 before the well targets had been reached. Well\r\n6406/2-4 S R was re-entered 12 November at depth 4534 m (4446 m TVD), below the\r\n9 5/8" casing shoe in the initial well, and drilled to final TD at 5080 m\r\n(4969 m TVD) in Early Jurassic Åre Formation sediments. The well bores were\r\ndrilled with KCl mud / spud mud down to 1110 m, with KCl mud and "ANCO 208"\r\nglycol from 1110 m to 2260 m, and with oil based "ANCOVERT" mud from\r\n2260 m to final TD. \u003c/p\u003e\r\n\r\n\u003cp\u003eDown to Base\r\nCretaceous Unconformity the stratigraphy was as expected, the prognosis matched\r\nthe experienced stratigraphy well. Below ECU, 154 meters of Upper Jurassic\r\nshales were penetrated before the drilling had to be stopped. Prognosed\r\nthickness of the Upper Jurassic shales was 44 m TVD. High total g","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"979","properties":{"OBJECTID":979,"wlbNpdidWellbore":3014,"wlbName":"15/6-8 S","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eBlock 15/6 is situated on the eastern\r\nflank of the southern part of the South Viking Graben, lying in a transition\r\nzone on a system of faulted terraces between the main Viking Graben to the west\r\nand the Utsira High to the east. The primary objective of the 15/6-8 S well was\r\nto test the hydrocarbon potential of the Middle Jurassic Hugin Formation within\r\na seismically defined structural trap. A secondary objective was the Heimdal\r\nFormation sandstone ("C-Prospect") which was prognosed to be\r\npenetrated in a down dip flank location, but within structural spill. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe sidetrack 15/6-8 A was designed to\r\ntest the "C-prospect" in a more optimal crestal location, some 1000 m\r\nto the west of the well position. \u003c/p\u003e\r\n\r\n\u003cp\u003eOther potential reservoir horizons\r\nexisted in the Early Tertiary Skade and Grid Formations. These were not within\r\nmapped structural closure in any of the well trajectories. The well programmes\r\nwere designed to maximise the evaluation of these sections.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eExploration well 15/6-8S was spudded with\r\nthe semi-submersible installation "Byford Dolphin" on 18 February\r\n1997 and drilled as a vertical hole to a depth of 1538 m, before kicking off in\r\na NNW direction towards the Middle Jurassic primary objective. The final TD was\r\nreached at 3225 m MD (3122.5 m TVD SS) in the Triassic Skagerrak Formation. The\r\nwell was drilled with Seawater and bentonite down to 512 m, with KCl / polymer\r\nmud from 512 to 1650 m, and with KCl / polymer / glycol from 1650 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe Quaternary and Tertiary sequence of\r\n2550 m thickness (2493 m True Vertical Thickness, TVT) was represented by the\r\nNordland, Hordaland and Rogaland Groups. Mudstone lithologies dominated, but\r\nsignificant thick sandstone development was present in the Utsira, Skade, Grid,\r\nand Heimdal Formations. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe Shetland Group comprised the Early\r\nPalaeocene Ekofisk and the Late Cretaceous, Tor, Hod, Blod°ks and Svarte\r","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"980","properties":{"OBJECTID":980,"wlbNpdidWellbore":3015,"wlbName":"7228/7-1 S","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 7228/7-1S is\r\nsituated in the Nordkapp basin. The Nordkapp basin is the most pronounced\r\nstructural element east of Loppa High, with a basinal-axis oriented NE-SW. From\r\ntop Cretaceous and down to TD of the well the sediments are steeply dipping due\r\nto salt diapirism, with the salt diapir located SE of the surface location. The\r\nmain objective of well 7228/7-1S was to test the hydrocarbon potential of the\r\nUpper Triassic Snadd Formation sandstones. Secondary objectives were to test\r\nthe hydrocarbon potential in Early to Middle Jurassic sandstones, the Stø,\r\nNordmela and Tubåen Formations, and the Middle Triassic Kobbe Formation\r\nsandstones. The well path is deviated and designed to penetrate below the salt\r\ndiapir. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well was\r\nspudded on 5 December 2000 with the semi-submersible installation \"Transocean\r\nArctic\" and drilled to a TD of 2087 m in Early Permian sediments. No shallow\r\ngas was expected, but since this was a new area a 9 7/8\" pilot hole was\r\ndrilled. No shallow gas was observed by the ROV. Tracks 7228/7-1 S and 7228/7-1\r\nS T2 were both finished in the Hekkingen Formation due to hole problems in the\r\n17 1/2\" section. The 7228/7-1 S track was drilled with sea water and\r\nhi-vis bentonite pills down to 372 m, with sea water / hi-vis pills /\r\npolymer-treated bentonite mud from 372 m to 507 m, with NaCl / Polymer from 507\r\nm to 709 m, and with sea water from 709 m to 1362 m. The 7228/7-1 S T2 track\r\nwas kicked of 7228/7-1 S at 1332 m and\r\ndrilled to 1348 m with a NaCl / sea water / polymer / glycol system. Track 7228/7-1 S T3 was kicked of from below the 20\" casing shoe in 7228/7-1 S\r\nand drilled with \"Glydril\" mud (KCl / Polymer / glycol) from 530 m to TD. The\r\nobserved formation tops were encountered shallower than prognosed, outside the\r\nuncertainty range. The deviation from prognosed depths increased with depth,\r\nfrom 79.0 m for the Cretaceous Knurr Formation to 229.5 m for the Triassic\r\nSnadd Formation. The Fuglen","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"981","properties":{"OBJECTID":981,"wlbNpdidWellbore":3025,"wlbName":"25/8-9 A","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 25/8-9 is\r\nlocated East-Northeast of the Jotun Field. The two main objectives for drilling\r\nwell 25/8-9 were to test the hydrocarbon potential of Early Palaeocene Heimdal\r\nFormation sandstones (Krap prospect) and secondly sandstones of the Middle\r\nJurassic Hugin Formation. The well found oil in the Early Heimdal Formation and\r\nit was decided to sidetrack (25/8-9 A) to appraise and test the hydrocarbon\r\npotential in this discovery.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eExploration well\r\n25/8-9 was spudded with the semi-submersible installation "Byford\r\nDolphin" on 5 January 1997 and drilled to TD at 2548 m in the Early\r\nJurassic Amundsen Formation. The well was drilled with seawater and\r\npre-hydrated bentonite sweeps down to 1110 m and with "Ancovert" oil\r\nbased mud from 1110 m to TD.& No shallow\r\ngas or boulder beds were encountered in the uppermost well section. Well 25/8-9\r\npenetrated mainly clays and claystones in the Nordland, Hordaland, and Rogaland\r\ngroups with both the Utsira (694 m to 905 m) and Grid (1300.5 m to1345.0 m)\r\nFormation sandstones being present. Interbedded shales and thin Heimdal\r\nFormation sands were encountered between 2096 and 2189 m and hydrocarbons were\r\nfound present in the uppermost reservoir section, however reservoir quality\r\nproved very poor. A FWL/OWC was not possible to define either from MDT\r\n(pressure) or logs, but an ODT at 2069 m TVD SS was established. Top Ty\r\nFormation was reached at 2228 m, consisting of upper clean sand divided by a\r\nshaly unit from a lower clean sandstone divided by a thin shale bed. It\r\ncontinued down to top Shetland Group at 2323 m. No hydrocarbons were found in\r\nthe Ty Formation. The Shetland Group consisted mainly of chalk with the Cromer\r\nKnoll Group consisting of limestones interbedded with claystones and marls. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe Hugin Formation\r\nsandstones came in at 2432 m and were found to be water bearing. One core\r\ntotalling 27 metres was cut in the interval 2098 m to 2126 m in the ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"982","properties":{"OBJECTID":982,"wlbNpdidWellbore":3042,"wlbName":"35/11-10","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 35/11-10 is located on the western\r\nedge of the Uer Terrace, ca 9 km North of the Troll Field. It was drilled to\r\nappraise the oil and gas discovery made in the exploration well 35/11-4, which\r\nencountered hydrocarbons in the Upper Sognefjord Formation separated from an\r\noil column in the Lower Sognefjord Formation, in the Fensfjord Formation, and\r\nin the Brent Group. In addition the Utsira Formation was to be cored in order\r\nto obtain information about the productivity for injection water.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eAppraisal well 35/11-10 was spudded with\r\nthe semi-submersible installation West Vanguard on 19 May 1997 and drilled to\r\nTD at 2950 m in the Early Jurassic Cook Formation. Some problems were\r\nencountered with coring in the Utsira Formation. In addition the Utsira\r\nFormation was not logged due to a tight spot at 439 m. Otherwise no significant\r\nproblems were encountered during operations. The well was drilled with spud mud\r\ndown to 1152 m and with ANCO 2000 glycol mud from 1152 m to TD. \u003c/p\u003e\r\n\r\n\u003cp\u003eFrom MWD logs and drilling parameters the\r\nUtsira Formation proved not to be developed as a sand reservoir in this\r\nlocation. The well confirmed hydrocarbons in all target levels except for the\r\nEtive Formation of the Brent Group. The top Sognefjord reservoir was\r\nencountered at 1971 m. The upper part of the Sognefjord Formation was thicker\r\nand had better reservoir properties than prognosed. A gas oil contact was\r\nidentified at 1987 m and an oil water contact at 2011 m. Within the range of\r\nuncertainty this was the same OWC as in the well 35/11-4 and there was pressure\r\ncommunication in both the water and the oil zones. The GOC however, differs\r\nbetween the two wells. A total of 14 m of gas pay and 22.6 m oil pay with an\r\naverage porosity of 27% were encountered. The Lower Sognefjord contained oil\r\nand gas with a thin gas cap at 2037 m identified by an MDT sample. The OWC was\r\nat 2054 m, which is the same depth as in well 35/11-4. Top Fensfjord Forma","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"983","properties":{"OBJECTID":983,"wlbNpdidWellbore":3060,"wlbName":"6306/5-1","wlbHistory":"\u003cp\u003eWildcat well 6306/5-1 was drilled ca 190\r\nkm West of the town Trondheim, on the Klakk Fault Complex, which forms the\r\nborder between the FrØya High and the MØre Basin. The two main objectives were\r\nto test the hydrocarbon potential of two Palaeocene prospects: the Eirikson\r\nprospect and the Nansen prospect. When drilled these prospects were prognosed\r\nas the Heimdal Formation sandstone and a new informal "Skalmen Formation\r\nsandstone", respectively. Only the Skalmen Formation was confirmed by the\r\nwell. Later this formation has been encountered in other wells in the area as\r\nthe (informal) Egga Formation. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 6306/5-1 was spudded with\r\nthe semi-submersible installation Deepsea Trym on 8 June 1997. Operations went\r\nwithout significant problems down to the 8 1/2" section. This section was\r\ndrilled from 1300 m to 1751 m, top of the Egga reservoir. This was found to be\r\nsignificantly over pressured and a large gain was taken. The well was shut-in\r\nand steps were taken to kill the well. The operation was complicated by the\r\ndiscovery that the pipe was stuck. The string was finally cut at 1477 m, and a\r\ncement plug was set to be used as kick-off plug for a sidetrack around the\r\nfish. The sidetrack was kicked off at 1365 m and drilled to TD at 2050 m in the\r\nLate Cretaceous Kvitnos Formation without further problems. The well was\r\ndrilled with bentonite and seawater down to 1001 m and with ANCO 2000 mud from\r\n1001 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eNo shallow gas or boulder beds were\r\nencountered in the uppermost well section. The well penetrated mainly clays and\r\nclaystones in the Nordland, Hordaland and Rogaland groups with minor sands\r\ndeveloped and limestone stringers present. The prognosed Heimdal Formation\r\nsands were not present. Top Egga sand was reached at 1751 m and was 12 m thick.\r\nThe lithology of the Egga sand was mainly a clean sandstone divided in two by a\r\ncalcareous clay stone. Top of the Egga reservoir was re-penetrated in the\r\nsidetrack at ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"984","properties":{"OBJECTID":984,"wlbNpdidWellbore":3062,"wlbName":"25/8-10 S","wlbHistory":" \u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n \r\n \u003cp\u003eWell 25/8-10 S is\r\n located north of the Grane Field. The well was drilled and tested to obtain\r\n representative fluid samples, production characteristics, and reservoir\r\n permeabilities in the Forseti Prospect in the Hermod - Middle Heimdal\r\n formation. \u003c/p\u003e\r\n \r\n \u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n \r\n \u003cp\u003eExploration well\r\n 25/8-10 S was spudded with semi-submersible drilling installation\r\n "Deepsea Trym" on 29 April 1997\r\n and drilled to TD at 1749.5 m in the Late Paleocene Lista Formation. The\r\n original 25/8-10 S well was drilled with a slightly deviated profile (+/- 6\r\n degree maximum angle) to a depth of 1749 m MD RKB. Due to a mechanical problem,\r\n which occurred after coring at 1722-1749 m, the well was plugged back and a\r\n technical sidetrack (25/8-10S T2) was kicked off at 1076 m and drilled to the\r\n original geologic objective at a total depth of 1890 m in the Early Paleocene\r\n Ekofisk Formation. Well 25/8-10 S was drilled with seawater and bentonite\r\n sweeps down to 1091 m and with oil based "Ancovert" mud from 1091 m\r\n to TD. The technical sidetrack 25/810 S T2 was drilled with oil based with\r\n "Ancovert" mud. The sidetrack\r\n penetrated 18 m (net pay) of oil filled sand in the Hermod - Middle Heimdal\r\n formation with an OWC, based on logs, at 1755.5 m TVD SS. The pay zone\r\n consisted of three sand intervals. One core was cut in the 25/8-10 S wellbore\r\n in the interval 1722 m to 1749.65 m (Sele, Hermod, and Lista Formations). A\r\n second core was cut in the 25/8-10 S T2 sidetrack in the interval 1749 m to\r\n 1786 m. (Lista and Heimdal Formations). After wire line logging the 25/8-10S T2\r\n well a drill stem test of the upper sand interval, in the Hermod Formation, was\r\n performed. Fluid samples were taken during the DST. The well was permanently\r\n abandoned on 5 June 1997 as an oil and gas discovery, named the 25/8-10 S\r\n Ringhorne Discovery.\u003c/p\u003e\r\n \r\n \u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n \r\n \u003cp\u003eThe interval from\r\n 1727.0 m to 1740.5 m (1698.6 - 1711.9 m TV","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"985","properties":{"OBJECTID":985,"wlbNpdidWellbore":3067,"wlbName":"16/7-6","wlbHistory":"\r\n\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWildcat well 16/7-6 is located ca 2 km\r\nsouth of the Sigyn Field. It was drilled to test the A-South prospect at\r\nTriassic level.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 16/7-6 was spudded with the\r\nsemi-submersible installation Stena Dee on 27 June 1997 and drilled to TD at\r\n2725 m in the Triassic Skagerrak Formation. A 36" hole was drilled from\r\n103 - 178 m. The 30" casing was set at 176.5 m. A 9 7/8" pilot hole\r\nwas drilled to 1160 m. No shallow gas was observed. The hole was opened up to\r\n17 1/2" down to 1160 m and the 13 3/8" casing was set at 1153 m. The\r\nwell was drilled with seawater down to 176.5 m and with Ancotec oil based mud\r\nfrom 1176.5 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well encountered the Skagerrak\r\nFormation sands at 2564 m. A total of 140.5 m of these sands were drilled\r\nbefore the well was terminated at 2725 m. Of this, petrophysical evaluation\r\ngave 134.4 m net sand with 20.3 % average porosity. The entire reservoir was\r\nwater bearing. No shows were reported from any section of the well.\u003c/p\u003e\r\n\r\n\u003cp\u003eTwo cores were cut from 2562 to 2626 m in\r\nthe Skagerrak Formation. Seven MDT water samples were taken at 2621.6 m.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 24\r\nJuly 1997 as a dry well.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test was performed\u003c/p\u003e\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"986","properties":{"OBJECTID":986,"wlbNpdidWellbore":3074,"wlbName":"15/12-11 S","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eExploration well 15/12-11 S was a joint\r\noperation of Production Licence 038 and 116. It was drilled in the northwestern\r\narea of block 15/12 and north of the Varg Field. Well 15/12-1 nearby to the\r\nnorthwest had shows in the Middle Jurassic Hugin Formation, but this was\r\ninconclusive with respect to moveable hydrocarbons. Block 15/12 is structurally\r\nlocated in the junction between the Jµren High to the southeast, the Ling\r\nDepression to the east, the Sleipner Terrace towards the north and the Witch\r\nGround Graben to the west. The prospect was defined as a multi-target\r\nstructure, situated on a rotated fault block. Primary targets were Tertiary\r\nsandstones of the Heimdal Formation in a genuine closure, in addition to\r\nsandstones of the Middle Jurassic Hugin Formation. Secondary high-risk targets\r\nwere sandstones of Eocene, Late Jurassic and Triassic age. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eExploration well 15/12-11 S was spudded\r\nwith the semi-submersible drilling installation "Deepsea Bergen" on\r\n10 April 1997 and drilled to TD at 3597 m (3464 m TVD RKB) in sandstones of the\r\nTriassic Skagerrak Formation. The well was drilled with seawater and hi-vis\r\npills down to 407 m and with KCl / polymer / Glycol (ANCO 208) mud from 407 m\r\nto TD. \u003c/p\u003e\r\n\r\n\u003cp\u003eSandstone was encountered in all of the\r\npossible prospective levels except in the Late Jurassic. The two primary\r\ntargets however, were more silt/shale dominated than expected. The upper part\r\nof the Heimdal Formation, penetrated at 2680 m had a lower reservoir quality\r\nthan expected. These distal parts of the formation were relatively shaly/silty.\r\nMore massive and porous sand of the Heimdal Formation was penetrated deeper,\r\nbut too deep with respect to a Maureen Field oil spill. The lower reservoir,\r\nthe Hugin Formation was penetrated at 3395 m, and was slightly thicker than\r\nprognosed. The only indications of hydrocarbons observed during drilling of\r\n15/12-11 S were weak shows in the Hegre and Vestland Groups a","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"987","properties":{"OBJECTID":987,"wlbNpdidWellbore":3075,"wlbName":"6707/10-1","wlbHistory":"\u003ch3\u003eGeneral \u003c/h3\u003e\r\n\r\n\u003cp\u003eWell\r\n6707/10-1 was the first well drilled in PL218 and the first in the Vøring Basin\r\ndeepwater area. The well targeted a tilted fault block on the Nyk High\r\ncomprising Late Cretaceous sandstones with a pronounced flat spot. The main\r\nobjectives of the well were to establish the presence, quality, and fluid\r\ncontent of the Campanian age Nise Formation. The underlying Santonian age\r\nLysing Formation provided a secondary target. \u003c/p\u003e\r\n\r\n\u003ch3\u003eOperations and results\u003c/h3\u003e\r\n\r\n\u003cp\u003eWildcat well 6707/10-1 was spudded with the semi-submersible\r\ninstallation \"Ocean Alliance\" on 19 April 1997 and drilled to TD at 5039 m in\r\nLate Cretaceous sediments of the Kvitnos Formation. The well was drilled water\r\nbased with \"BARASILC\" silicate mud with KCl and GEM GP (glycols) from 2240 m to\r\n2890 m and with KCl/NaCl/GEM GP/Polymer mud from 2890 m to TD. Top Nise Formation\r\nwas penetrated at 2957 m, 1 m deeper than the revised depth prognosis based on\r\nan intermediate VSP run. The reservoir was\r\nrecognized by an abrupt decrease in LWD gamma combined with increased gas levels\r\nand the appearance of sand in the cuttings. Wire line logging and sampling\r\nconfirmed a gas column from 2957.5 to 3113.5 m. A total of nine cores were\r\ncut over the interval 2967 - 3145 m with a total recovery of 171 m (96 %).\r\nPoor shows were recorded in cores throughout this reservoir section, down to\r\nthe base of core 9, where moderate shows were seen in the interval 3140 - 3145\r\nmBRT. One 27 m core (core 10) was cut in the secondary target (4118 - 4145\r\nmBRT). This core had fair shows at the top. No shows were seen in the drilled\r\ncuttings. Altogether 10 MDT fluid samples were taken in the Nise Formation.\r\nSeven of these were taken from 2964 to 3086 m RKB in the reservoir zone, two\r\nsamples were from 3114.5 m just below the gas-water contact, and one from\r\nfurther down at 3195 m. The MDT samples were contaminated with mud, but PVT\r\nflash to stock tank conditions gave a consistent gas gravity of 0.59 relative\r\n\r\nto air and a GOR in excess","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"988","properties":{"OBJECTID":988,"wlbNpdidWellbore":3077,"wlbName":"15/6-8 A","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eBlock 15/6 is situated on the eastern\r\nflank of the southern part of the South Viking Graben, lying in a transition\r\nzone on a system of faulted terraces between the main Viking Graben to the west\r\nand the Utsira High to the east. The primary objective of the 15/6-8 S well was\r\nto test the hydrocarbon potential of the Middle Jurassic Hugin Formation within\r\na seismically defined structural trap. A secondary objective was the Heimdal\r\nFormation sandstone ("C-Prospect") which was prognosed to be\r\npenetrated in a down dip flank location, but within structural spill. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe sidetrack 15/6-8 A was designed to\r\ntest the "C-prospect" in a more optimal crestal location, some 1000 m\r\nto the west of the well position. \u003c/p\u003e\r\n\r\n\u003cp\u003eOther potential reservoir horizons\r\nexisted in the Early Tertiary Skade and Grid Formations. These were not within\r\nmapped structural closure in any of the well trajectories. The well programmes\r\nwere designed to maximise the evaluation of these sections.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eExploration well 15/6-8S was spudded with\r\nthe semi-submersible installation "Byford Dolphin" on 18 February\r\n1997 and drilled as a vertical hole to a depth of 1538 m, before kicking off in\r\na NNW direction towards the Middle Jurassic primary objective. The final TD was\r\nreached at 3225 m MD (3122.5 m TVD SS) in the Triassic Skagerrak Formation. The\r\nwell was drilled with Seawater and bentonite down to 512 m, with KCl / polymer\r\nmud from 512 to 1650 m, and with KCl / polymer / glycol from 1650 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe Quaternary and Tertiary sequence of\r\n2550 m thickness (2493 m True Vertical Thickness, TVT) was represented by the\r\nNordland, Hordaland and Rogaland Groups. Mudstone lithologies dominated, but\r\nsignificant thick sandstone development was present in the Utsira, Skade, Grid,\r\nand Heimdal Formations. \u003c/p\u003e\r\n\r\n\u003cp\u003eThe Shetland Group comprised the Early\r\nPalaeocene Ekofisk and the Late Cretaceous, Tor, Hod, Blod°ks and Svarte\r","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"989","properties":{"OBJECTID":989,"wlbNpdidWellbore":3084,"wlbName":"2/5-11","wlbHistory":"\u003cb\u003e\r\nGeneral\r\n\u003c/b\u003e\r\n\u003cp\u003e\r\nWell 2/5-11 was drilled primarily to explore the Sørimne prospect located in the southwestern part of PL 067, which is north of the existing Tor field. The prospect was a stratigraphic chalk play thought to be separate from the hydrocarbon-bearing formation in the nearby well 2/5-7. The main purpose for drilling the well 2/5-11 was to test the hydrocarbon potential within the Maastrichtian Tor formation. A secondary target was to test the hydrocarbon potential in the Ekofisk Formation Tjatse prospect.\r\n\u003c/p\u003e\r\n\u003cb\u003e\r\nOperations and results\r\n\u003c/b\u003e\r\n\u003cp\u003e\r\nThe 2/5-11 well was spudded on 6 September 1997. \"Transocean Nordic\", a Jack-Up Rig, was used to drill and abandon the well. Operations took 20 days longer than planned. Main reasons for the extended time were 2 days of unplanned coring and 9 days waiting on weather. The well was drilled to a total depth of 3550 m in the Tor formation in the chalk. High viscosity bentonite mud was used to 780 m. From 780 m to TD the well was drilled water based with various combinations of KCl, polymer, PAC, and glycol.\r\n\u003cbr\u003e\r\nThe expected reservoir was encountered at 3362 m, 2 m deeper than prognosed. A FMT fluid sample containing mainly mud filtrate, some gas and small amounts of floating scummy oil was taken at 3444.3 m. An extensive logging program was employed to evaluate the Chalk sequence. After logging was completed, the logging information indicated that hydrocarbons were present and down hole testing was performed. Testing the well in two zones showed that, although hydrocarbons were present, there was a high content of water. Four cores were cut, one in the Ekofisk Formation (3312 m - 3330 m), one across the Ekofisk - Tor boundary (3330 m - 3366 m), and two in the Tor Formation (3393 m - 3419 m and 3418 m - 3465 m). The well was permanently plugged and abandoned as an oil discovery.\r\n\u003c/p\u003e\r\n\u003cb\u003e\r\nTesting\r\n\u003c/b\u003e\r\n\u003cp\u003e\r\nTwo tests were performed in the well. Test 1 in interval 3363 - 3381 m in the Tor Formation produced a total of 3.8 Sm3 of 38.7 API gravity","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"990","properties":{"OBJECTID":990,"wlbNpdidWellbore":3085,"wlbName":"34/10-41 S","wlbHistory":"\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eGeneral\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWell 34/10-41 S was drilled west of the\r\nGullfaks Field and slightly south of the Tordis Field on the Tampen Spur in the\r\nNorth Sea. The primary objective was to test the hydrocarbon potential in the\r\n"A-prospect" at Middle Jurassic Brent Group level. The secondary\r\nobjective was to test the Early Jurassic Statfjord Group.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cb\u003e\u003cspan lang=EN-GB\u003eOperations and results\u003c/span\u003e\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eWildcat well 34/10-41 S was spudded with\r\nthe semi-submersible installation Deepsea Trym on 13 July 1997 and drilled to\r\nTD at 3420 m in the Early Jurassic Statfjord Group. At 3098 m problems with\r\nsteering and hole angle made it necessary to sidetrack in order to reach the\r\nplanned secondary target at top Statfjord Group. The well was plugged back ca\r\n270 m and sidetracked (34/10-41 S T2) from 2913 m. The well was drilled with\r\nspud mud down to 1050 m and with Quadrill KCl/glycol mud in both well tracks\r\nbelow 1050 m to TD.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eThe top of the Brent Group was penetrated\r\nat 2553 m, approximately 18 m above the prognosed depth, and proved to be dry.\r\nThe seismic anomaly in top of the prospect turned out to be a lithology effect.\r\nFrom the claystone in the Heather Formation, a very calcareous sandstone was\r\npenetrated in the Tarbert Formation. It is believed that this transition to a\r\nhigh velocity layer is the cause of the amplitude. The Statfjord Group was\r\npenetrated at 3367.5 m and was also proven dry. Except for occasional\r\nfluorescence and cut in claystones between 2472 m and 2775 m there were no\r\nshows in the well. The lack of migrated oil was in agreement with post-well\r\norganic geochemical analyses, where extracts proved to be more or less\r\ncontaminated by the mud and devoid of typical migrated hydrocarbons.\u003c/span\u003e\u003c/p\u003e\r\n\r\n\u003cp class=MsoBodyText\u003e\u003cspan lang=EN-GB\u003eNo cores were cut and no wire lin","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"991","properties":{"OBJECTID":991,"wlbNpdidWellbore":3087,"wlbName":"9/2-7 S","wlbHistory":"\u003cb\u003e\r\nGeneral\r\n\u003c/b\u003e\r\n\u003cp\u003e\r\nThe deviated well 9/2-7 S was drilled as an exploration well to identify the oil potential in the Beta Vest prospect on the Yme Field in PL 114. The well was drilled in the northern segment of the Beta Vest structure with the sandstones of the Sandnes Formation as the target horizon. The well was planned to be completed as an oil producer and be renamed to 9/2-B-3H.\r\n\u003c/p\u003e\r\n\u003cb\u003e\r\nOperations and results\r\n\u003c/b\u003e\r\n\u003cp\u003e\r\nWildcat well 9/2-7 S was spudded with the semi-submersible installation \"Byford Dolphin\" on 22 April 1997 and drilled to a total depth of 4099 m (3369.7 m TVD MSL) in the Middle Jurassic Bryne Formation. It was drilled from slot 3 on the Yme Beta HOST template with an \"S\" shaped profile in order to drill vertically through the Sandnes Formation. The Sandnes S12 target was penetrated approximately 1757 m North North-West of the template, at an inclination of about 5 deg. A 7\" liner was run over the reservoir section. The bottom section fro 3923 m to TD was drilled with turbine and diamond bit. The well was drilled with seawater to 1192 m, with KCl polymer mud from 1192 m to 256 m, with ester-based Petrofree mud from 2576 m to 3867 m, and with Aquadrill glycol mud from 3867 m to TD.\r\nThe well found oil all through the Sandnes Formation. The top of the Sandnes Formation was encountered at 3854 m (3125.6 m TVD MSL), with the top of the Sandnes Formation S11 reservoir sandstone at 3861,7 m (3133,3 m TVD MSL). The oil/water-contact was found in the Bryne Formation sandstones at 4067m MD (3337.9 m TVD MSL). Two cores were cut in the interval 3868 m - 3923 m in the Sandnes Formation. Two FMT fluid samples were taken at 3896 m in the Sandnes Formation oil zone. Exploration well 9/2-7 S was completed 10 June 1997 as an oil discovery and re-classified to development well 9/2-B-3 H.\r\n\u003c/p\u003e\r\n\u003cb\u003e\r\nTesting\r\n\u003c/b\u003e\r\n\u003cp\u003e \r\nNo drill stem test was performed.\r\n\u003c/p\u003e\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"992","properties":{"OBJECTID":992,"wlbNpdidWellbore":3092,"wlbName":"6407/8-3","wlbHistory":"\u003cb\u003e\r\nGeneral\r\n\u003c/b\u003e\r\n\u003cp\u003e\r\nIn 1994 well 6407/8-2 was drilled on the block 6407/8 \"Tau\" prospect, resulting in the discovery of a sub commercial accumulation in the Jurassic. Based on later acquired 3D survey (BPN9501) the prospectivity in the license was re-evaluated by BP in 1996, and exploration well 6407/8-3 was drilled to test the block 6407/8 \"Draugen West\" prospect. This was a Jurassic prospect lying between the Draugen field and the 6407/8-2 Tau accumulation, defined as a structural - stratigraphic combination trap. The primary target was the Jurassic Ile sandstone; the secondary target was the Tilje formation.\r\n\u003c/p\u003e\r\n\u003cb\u003e\r\nOperations and results\r\n\u003c/b\u003e\r\n\u003cp\u003e\r\nExploration well 6407/8-3 was spudded with the semi-submersible installation \"Mærsk Jutlander\" on 13 May 1997 and drilled to TD at 1960 m in the Early Jurassic Åre Formation. The well was drilled with a water based silicate mud. It was drilled riser less to 1052 m; no logs or cuttings were obtained from above this point. \r\n\u003c/p\u003e\r\n\u003cp\u003e\r\nWell 6407/8-3 successfully penetrated both reservoirs. The average net porosity in both the Ile and Tilje formations was over 30% and the cuttings indicated this was highly unconsolidated, although there were significant interbedded shales within the sand. Gas levels were generally low with total gas never going above 0.2 %. Traces of C2 - C4 were observed over the Jurassic section. Some indications of residual hydrocarbons were seen in the logs, otherwise no trace of movable hydrocarbons was found within the two reservoirs. Geochemical extraction of SWC in an on-shore laboratory (LGC ltd in UK) proved small amounts of hydrocarbons through the entire Ile formation and at least parts of the Tilje formation. The last 14.5 metres of the well were not logged due to hole problems. No RFT points or other direct pressure measurements were taken. No fluid samples were taken. No cores were taken.\r\n\u003c/p\u003e\r\n\u003cp\u003e\r\nThe well was permanently abandoned as a dry well with shows on 27 May 1997.\r\n\u003c/p\u003e\r\n\u003cb\u003e\r\nTesting \r\n\u003c/b\u003e\r\n\u003cp\u003e\r\nNo drill stem test ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"993","properties":{"OBJECTID":993,"wlbNpdidWellbore":3098,"wlbName":"25/10-8 A","wlbHistory":"\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 25/10-8 was drilled with \"Deep Sea\r\nTrym\" to test the Hanz prospect with multiple targets. The well found gas and\r\noil in the Upper Jurassic. A sidetrack, 25/10-8 A, was drilled to test the\r\nextension of this discovery to the east. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eExploration well 25/10-8 was spudded with\r\nthe semi-submersible installation \"Deepsea Trym\" 17 February 1997 and drilled to a total depth of 2653 m in the\r\nEarly Permian Rotliegend Group. Water based mud was used down to 1080 m and an\r\nAncoVert oil based mud from 1080 to TD. Well 25/10-8 found the Heimdal Fm to be\r\nwater wet, the Upper Jurassic sands to contain gas and oil and the Middle\r\nJurassic and Rotliegendes sands to be water wet. A core was cut from 2080 -\r\n2107 m in the Heimdal Formation, a second core was cut from 2518 - 2546 m in\r\nCallovian Jurassic to Triassic sediments. After testing the well was plugged\r\nback to the 13 3/8" casing on 4 April 1997 as an oil and gas\r\ndiscovery. Sidetrack 25/10-8 A was\r\nkicked off from 1067 m and drilled to a total depth of 3460 m (2537 m TVD RKB)\r\nin Late Jurassic. An 8 1/2" hole was drilled to core point at 3110 m using\r\noil based mud. Three cores were cut in the Late Jurassic; 3110 to 3147 m, 3147\r\nto 3165 m , and 3165 to 3202 m. No wireline logs were run in well 25/10-8 A,\r\nonly MWD. No fluid samples were taken. All reservoir sands were found water wet\r\nand sidetrack 25/10-8 A was permanently abandoned as a dry well on 27 April\r\n1997.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 25/10-8 was perforated from 2391.4 -\r\n2398.4 m in the Upper Jurassic. The drill stem test flowed 692 Sm3/D oil of\r\ndensity 0.84 g/cm3. No drillstem test was performed in 25/10-8 A. \u003c/p\u003e\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"994","properties":{"OBJECTID":994,"wlbNpdidWellbore":3113,"wlbName":"15/5-6","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 15/5-6 was drilled on the Glitne\r\nfield in the North Sea. The main objective was to appraise the 15/5-5 Glitne\r\noil discovery in the Heimdal Formation. The secondary objective was to\r\ninvestigate the oil potential of a separate "Intra Lista Sandstone"\r\nwhich had been mapped as a sequence lapping onto the main Heimdal Formation. \u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eAppraisal well 15/5-6 was spudded with\r\nthe semi-submersible installation Byford Dolphin on 20 June 1997 and drilled to\r\nTD at 2725 m in the Paleocene Ekofisk Formation. The drilling went according to\r\nplan. However, problems due to poor hole conditions were encountered during\r\nwire line logging at TD. The well was drilled with seawater and hi-vis pills\r\ndown to 1002 m and with KCl/polymer/glycol mud from 1002 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe top of the main Heimdal reservoir was\r\npenetrated 39 m TVD deeper than prognosed. The top corresponded seismically to\r\nthe reflector that pre-drill was interpreted as the top "Intra Lista\r\nSandstone", so the general consensus is now that the reflector is actually\r\nthe top Heimdal Formation and that the "Intra Lista Sandstone"\r\nsequence is not present.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe uppermost part of the Heimdal\r\nreservoir was oil bearing, exhibiting good reservoir properties. The OWC was\r\nfound at 2185 m (2160 m TVD MSL), equivalent to the contact in well 15/5-5. No\r\nother parts of well 15/5-6 contained hydrocarbons or shows of hydrocarbons.\u003c/p\u003e\r\n\r\n\u003cp\u003eOne core was cut in the upper part of the\r\nHeimdal Formation. No fluid sample was taken in the well.\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was permanently abandoned on 16\r\nJuly 1997 as an oil appraisal.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eThe well was not production tested due to\r\nthe limited oil column and no "Intra Lista Sandstone" being present.\u003c/p\u003e\r\n\r\n\r\n\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"995","properties":{"OBJECTID":995,"wlbNpdidWellbore":3114,"wlbName":"25/7-4 S","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eBlock 25/7 is\r\nsituated in the South Viking Graben on the western side of the Utsira High, a\r\nbasement high that tilts slightly towards the east. The South Viking Graben has\r\nan asymmetrical profile bounded in the west by the Brea/Crawford Fault Zone and\r\nthe Utsira High to the east. The Jotun Field is sitting on a basement terrace\r\nstepping up to the Utsira High from the Graben area. Well 25/7-1 drilled in\r\n1986 for a Jurassic target encountered oil shows in thin ratty sands in the Paleocene\r\nHermod Formation. \u003c/p\u003e\r\n\r\n\u003cp\u003eExploration well\r\n25/7-4 S was drilled to test the 25/7 Hermod South prospect, a stratigraphic\r\ntrap comprising of channelised basin floor sandstones of the Paleocene Hermod\r\nFormation. The primary objectives of the well were to test the presence of\r\nhydrocarbons in the Hermod South prospect and to establish hydrocarbon type(s)\r\nand fluid contacts (if present). A secondary objective was to evaluate the\r\nLower Tertiary interval by ensuring that the well penetrates into the\r\nCretaceous.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eExploration well\r\n25/7-4 S was spudded with the semi-submersible installation "Maersk\r\nJutlander" on 2 June 1997 and drilled to a total depth of 2560 m in the\r\nLate Cretaceous Tor Formation. Operations went without problems within the AFE\r\ntime budget. The well was drilled with seawater and hi-vis pills down to 1195 m\r\nand with KCl / Glycol mud from 1195 m to TD. Good quality Hermod sands were\r\nencountered at 2018 m (1987 m TVD SS). Also the Heimdal and Ty Formation sands\r\nwere present. However, no indications of hydrocarbons were found. \u003c/p\u003e\r\n\r\n\u003cp\u003eNo conventional core\r\nwas cut in and no fluid samples were taken. The well was permanently abandoned\r\nas a dry well on 21 June 1997.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eTesting\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eNo drill stem test\r\nwas performed.\u003c/p\u003e\r\n","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"996","properties":{"OBJECTID":996,"wlbNpdidWellbore":3117,"wlbName":"25/11-19 SR","wlbHistory":" \u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n \r\n \u003cp\u003eWell 25/11-19 S was\r\n drilled on Licence 001, awarded in the first licence round in 1965. It was the\r\n last appraisal well on the Balder Field before it was decided to go ahead with\r\n Plan for Development in 1995. The well was located to penetrate the top\r\n reservoir of " Balder Mound 6" in a well-defined structurally high\r\n position. The primary target was a massive sand in the Hermod Formation; the\r\n secondary target was the Eocene Balder Formation Sand. The general objective of\r\n well 25/11-19 S was to reduce the range of uncertainty associated with the\r\n reserve basis for Balder Mound 6. The well was drilled as a directional well\r\n for potential re-entry as a future horizontal producer. \u003c/p\u003e\r\n \r\n \u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n \r\n \u003cp\u003eAppraisal well\r\n 25/11-19 S was spudded with the semi-submersible installation "Vildkat\r\n Explorer" on 24 April 1995 and drilled to TD at 2250 m (2019 m TVD SS) in\r\n Triassic (Late Rhaetian) sediments of the Statfjord Formation. The well was\r\n drilled with seawater spud mud down to 1015 m and with oil based "Safemul"\r\n mud from 1015 m to TD. Shallow gas was neither prognosed nor observed. The well\r\n was drilled vertically down to 1032 m before starting to build angle and at top\r\n of the primary target, the Hermod sand, the deviation was 38.2deg.  at an azimuth\r\n of 170.4deg. An 8 1/2" inch hole was drilled to an intermediate depth of\r\n 2096 m where an extensive wire line logging program was performed. Then an 8\r\n 1/2" hole was drilled to TD of 2250 m and final logging was performed. The\r\n 25/11-19 S confirmed oil in the Hermod sand. A good oil water contact was\r\n defined by wire line logs, extensive MDT sampling and pressures at 1922.5 m\r\n (1760.5 m TVD SS) in the Hermod reservoir sand. Furthermore, gas reserves were\r\n proved in the secondary target, the Balder Formation sand, and pressure data\r\n indicated a potential GOC at 1839.2 m (1694.8 m TVD SS). Three cores were cut\r\n in the Sele and Hermod Forma","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"997","properties":{"OBJECTID":997,"wlbNpdidWellbore":3125,"wlbName":"6406/2-5","wlbHistory":"\u003cb\u003e\r\nGeneral\r\n\u003c/b\u003e\r\n\u003cp\u003e\r\nWell 6406/2-5 was the second well drilled on the Kristin structure in the north-western part of block 6406/2, south-west of the Smørbukk Field and north-west of the Lavrans Field on Haltenbanken). The discovery well 6406/2-3 was drilled high on the structure; it tested gas and condensate in a down-to situation in both the Garn and the Ile Formations. The main objective of well 6406/2-5 was to test the hydrocarbon potential of the Garn and Ile Formations in a down flank position. In addition the well would test a secondary reservoir target of late Jurassic age, the Rogn sandstone, which was predicted based on seismic observations. \r\n\u003c/p\u003e\r\n\u003cb\u003e\r\nOperations and results\r\n\u003c/b\u003e\r\n\u003cp\u003e\r\nAppraisal well 6406/2-5 was drilled with the semi-submersible drilling installation \"Deepsea Bergen\".  The well was spudded on 3 June 1997 and drilled to TD at 5439 m in the Åre Formation. It was drilled with spud mud down to 1407 m, with KCl mud from 1407 m to 2612 m, and with oil based mud from 2612 m to TD.\r\nNo hydrocarbon bearing formations were encountered in well 6406/2-5. Hydrocarbon shows were observed in both the Garn and Ile Formations, but wire line logs, pressure measurements and fluid samples proved the well to be dry. In the well position the Viking Group consisted of the Spekk and Melke Formation shales, while the Late Jurassic Rogn sandstone was not observed. \r\nThe Garn Formation in well 6406/2-5 had distinctively reduced permeabilities and slightly reduced porosities compared to the parameters of well 6406/2-3. The low permeabilities of the Garn Formation made it difficult to perform pressure measurements, thus no reliable pressure gradient could be established in the Garn Formation.\r\nThe Ile Formation reservoir parameters in well 6406/2-5 were similar to what was experienced in well 6406/2-3, with variable, but in parts excellent porosity and permeability values. Water gradients were established based on pressure measurements in the Ile, Tofte, Tilje and Åre Formations. \r\nPore pressures of the Jura","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"998","properties":{"OBJECTID":998,"wlbNpdidWellbore":3126,"wlbName":"9/2-8 S","wlbHistory":"\u003cb\u003e\r\nGeneral\r\n\u003c/b\u003e\r\n\u003cp\u003e\r\nWell 9/2-8 S was drilled from slot 3 of the Yme template. The well was planned as an exploration well, to identify the hydrocarbon potential of the Yme Epsilon East and West structures. The well design was based on flexibility to enable later completion as a production well if commercial reserves of oil were encountered. The Epsilon East and West structures are developed on the east and west sides of a salt diapir. The well was planned to drill down through the sequence on the east flank with the Sandnes Formation being the primary target. As a secondary target the well was planned to extend a further 1600 m into Epsilon West structure. This involved drilling through the base of the salt diapir and then up through the sequence within the western flank.\r\nThe Epsilon East structure was recognized as a fairly well defined prospect, comprising of an eastward dipping tilted fault block. Complicated tectonism affecting the Epsilon West structure however, meant this could only have the status of a lead. The main uncertainties with respect to probability of discovery were considered as leakage/trap and source/migration.\r\n\u003c/p\u003e\r\n\u003cb\u003e\r\nOperations and results\r\n\u003c/b\u003e\r\n\u003cp\u003e\r\nWildcat well 9/2-8 S was spudded from the seabed with the jack-up installation \"Mærsk Giant\" on 24 June 1997. At 5936 m the BHA became stuck while drilling the Sandnes Formation. The well was subsequently sidetracked to 9/2-8S T2 from 5680 m on the 4 October 1997. The T2 sidetrack was only drilled to 6011 m due to the BHA becoming stuck at 6002 m while pulling out of hole. A further sidetrack, 9/2-8S T3, was drilled from 5628.5 m, on 19 October 1997 and reached a TD of 7203 m on 16 December 1997. This sidetrack failed to penetrate the Vestland Group, passing from Zechstein salts of the faulted zone straight into the shales of the Tau Formation. As a result a final sidetrack, 9/2-8S T4, was started from 6144 m on 21 December 1997. This wellbore reached final TD at 7584 m in the Late Jurassic Egersund formation on 18 January 1998 after ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"999","properties":{"OBJECTID":999,"wlbNpdidWellbore":3131,"wlbName":"6507/7-11 S","wlbHistory":"\r\n\u003cp\u003e\u003cb\u003eGeneral\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 6507/7-11 S was drilled to test a\r\n3-way dip closed structure (Heidrun SW) between the Smørbukk Field to the\r\nsouthwest and the Heidrun Field to the northeast. The Heidrun SW prospect\r\nconsists of a downthrown fault closure, W-segment and an independent up-thrown\r\nthree way dip-closure; the SW-segment. The trap is a structural hanging wall\r\ntrap, and formed as a consequence of Late Jurassic to Middle Cretaceous\r\nextensional tectonics. The prospect has a 3-way dip closure to the north, west\r\nand south and an up-thrown fault closure to the east, requiring a fault seal in\r\norder to have hydrocarbons present. The primary objective was to prove up\r\ncommercial reserves for the Heidrun SW structure, by testing the hydrocarbon\r\npotential of the Middle Jurassic Fangst Group, by means of wire line logging\r\nand coring. Secondary objectives were to test the Early Jurassic Tilje and Åre\r\nreservoirs and the Early Cretaceous sandstones for Hydrocarbon potential. The\r\nflowing potential and productivity of a discovery, if made, should be evaluated\r\nby MDT and DST-tools. If no indications of hydrocarbons in Late Tilje were\r\nfound, the well would reach TD at 3706 m TVD RKB (3710 m MD RKB) or 50 m below\r\ntop Tilje Formation. If hydrocarbons were present, the well would reach TD\r\ndeeper, at 3926 m TVD RKB (3930 mMD RKB) or 270 m below top Tilje.\u003c/p\u003e\r\n\r\n\u003cp\u003e\u003cb\u003eOperations and results\u003c/b\u003e\u003c/p\u003e\r\n\r\n\u003cp\u003eWell 6507/7-11 S was spudded with the\r\nsemi-submersible installation Mærsk Jutlander on 25 June 1997 and drilled to TD\r\nat 3749 m (3744 m TVD RKB) in the Early Jurassic Tilje Formation. The well was\r\ndrilled with Seawater and hi-vis pills down to 754 m and with KCl glycol\r\nenhanced mud from 754 m to TD.\u003c/p\u003e\r\n\r\n\u003cp\u003eNearly 40 m net thickness (of 100 m\r\ngross) of Fangst Group sandstones was encountered. Apart from elevated high\r\nbackground levels of mud gas in the interval 1500 m to 1540 m (7% to 11%) the\r\nwell was practically devoid of hydrocarbon indications and the target reservoir\r\nzones in the Fangst and Båt","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}},{"type":"Feature","id":"1000","properties":{"OBJECTID":1000,"wlbNpdidWellbore":3132,"wlbName":"25/7-5","wlbHistory":"\u003cb\u003e\r\nGeneral\r\n\u003c/b\u003e\r\n\u003cp\u003e\r\nWell 25/7-5 was the first exploration well drilled in PL203 and was designed to test the hydrocarbon potential of a sand prospect within the Sele Formation in the northwest corner of block 25/7. This prospect was a stratigraphic trap with structural elements formed by the pinch out of the Hermod T80 sand. Oil was prognosed to be encountered within the Hermod T80 sand. A very small closure in the top of the underlying Heimdal sand was also expected to contain hydrocarbons, but this closure was not defined as a secondary target due to the small volumes expected within the structure. The well commitment was to drill to a total depth of 2735 m within the Shetland Group. The objectives of the well were to test commercial oil volumes within the Hermod T80 sand, to test the geological and geophysical models for the presence of the Hermod T80 sand, and to test the model for hydrocarbon migration within the license area.\r\n\u003c/p\u003e\r\n\u003cb\u003e\r\nOperations and results\r\n\u003c/b\u003e\r\n\u003cp\u003e\r\nThe semi-submersible drilling rig \"West Vanguard\" was used to drill wildcat well 25/7-5. The well was spudded 16 July 1997 and reached a total depth of 2736m on the 7 August 1997 in the Early Paleocene Våle Formation\r\nThe well was drilled water based with spud mud to 1338 m and with the ANCO 2000 mud system from 1338 m to TD. Total rig time for the well, including testing, was 46.7 days. \r\n\u003cbr\u003e\r\n\u003cbr\u003e\r\nOil was encountered within the Hermod T80 sands between 2044 - 2052 m. There was 3.5 m of net reservoir within the interval (N/G 0,4372) with an average porosity of 0.25 and an excellent permeability of up to 6 Darcy. The rest of the non-reservoir sand was tightly cemented with calcite. No Oil-Water contact was seen in these sands.\r\n\u003cbr\u003e\r\nThe Heimdal formation was penetrated at 2126 m and contained approximately 1m of oil in the top of the reservoir (0.85 gm/cc density). The reservoir quality of these sands is excellent with an average porosity of 0.234 and permeabilities in the low Darcy range. Approximately 6m of residual hydrocarbons ","wlbHistoryDateUpdated":"2026-02-24T00:00:00"}}],"links":[{"href":"https://factmaps.sodir.no/api/rest/services/Factmaps/FactMapsWGS84/OGCFeatureServer/collections/254/items?crs=CRS84&bbox-crs=CRS84&properties=*&returnGeometry=true&resultType=results&offset=0&f=application/geo+json","rel":"self","type":"application/geo+json","title":"this document"},{"href":"https://factmaps.sodir.no/api/rest/services/Factmaps/FactMapsWGS84/OGCFeatureServer/collections/254/items?crs=CRS84&bbox-crs=CRS84&properties=*&returnGeometry=true&resultType=results&offset=0&f=text/html","rel":"alternate","type":"text/html","title":"this document as HTML"},{"href":"https://factmaps.sodir.no/api/rest/services/Factmaps/FactMapsWGS84/OGCFeatureServer/collections/254/items?crs=CRS84&bbox-crs=CRS84&properties=*&returnGeometry=true&resultType=results&offset=1000&f=application/geo+json","rel":"next","type":"application/geo+json","title":"next page"}],"timeStamp":"2026-06-04T19:57:38Z","numberReturned":1000}