{
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  "LayerId" : 254,
  "LayerName" : "Wellbore - History",
  "id" : "90",
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    "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"
  }
}