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