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  "LayerName" : "Wellbore - History",
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    "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"
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}