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