{
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  "LayerId" : 254,
  "LayerName" : "Wellbore - History",
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    "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"
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}