7225/3-1
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General information
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Wellbore history
GeneralWell 7225/3-1 was the first well to be drilled on the faulted Norvarg Dome on the Bjarmeland Platform in the Barents Sea. It was drilled fairly close to the crest of the structure. The primary objective was to prove hydrocarbon presence, determine fluid nature and evaluate reservoir characteristics in sandstones of the Late Triassic (Carnian) Lower Snadd Formation and the Early Triassic Kobbe Formation. Secondary objective was to prove hydrocarbons in the Jurassic Stø Formation, the Early Triassic Havert Formation, and the Permian Tempelfjorden and Bjarmeland groups.Operations and resultsWildcat well 7225/3-1 was spudded with the semi-submersible installation West Phoenix on 30 April 2011 and drilled to TD at 4150 m in the Permian Isbjørn Formation. No major drilling problems were encountered, but P&A in the upper part was subject to extensive delays associated with trying to retrieve casing, failed cement plugs or leak in 20" casing and extra time spent trying to locate the source of a gas leak. The well was drilled with bentonite mud with hiv-vis pills down to 672 m, and with KCl/polymer mud from 672 m to TD.Gas was proven both in intervals from the Jurassic and the Triassic. The Jurassic Stø Formation was gas bearing from top at 726 m to a likely GWC at 766.5 m. In the Triassic the upper part of the Snadd Formation with top at 804 m was supposed to be gas bearing, but this was not proven by sampling. The best Snadd sands, below 1040 m, could be sampled and they were water bearing. An Intra-Carnian section was penetrated from 1146 m to 1521 m. It contained gas in two zones with GWC's at 1218 m and ca 1250 m, respectively, and in a third thin sandstone from 1347 m to 1357 m. The upper and the lowermost Intra-Carnian gas zone were confirmed by MDT sampling. The Kobbe Formation was encountered at 1521 m. It is 634 m thick with 27.5% net/gross based on petrophysical evaluations. Gas was tested in numerous thin sandstone beds from 1557 m to 1779 m by MDT sampling and by a DST. The Havert Formation with top at 2554 m had only poorly developed reservoir rocks. MDT testing failed, but it was assumed to be gas bearing as well based on logs.Rig site analyses of fluorescence (oil shows) and by GCMS analyses of up to C7 components in mud gas ("FLAIR analysis") suggested that the Stø and upper Snadd gas zones were oil-associated. The deeper gas zones were practically devoid of liquid components based on these analyses.Four conventional cores were cut. Core 1 was cut in intra-Carnian sandstone and claystone from 1204-1258 m with 98% recovery. Core 2 was cut in the Kobbe Formation from 1675 to 1695 m with 83.3% recovery (jammed off). Core 3 was cut from 2610 to 2637 m in the Havert Formation with 100% recovery. Core 4 was cut from 4013 to 4016 m in the Isbjørn Formation with 15% recovery (jammed off). During two successful MDT wire line runs a total of 9 sampling stations were performed. Samples were taken at 1090.01 m (Snadd Formation; water+gas), 1121.98 m (Snadd Formation water), 1215.26 m (Intra-Carnian Sandstone; gas), 1279.99 m (Intra-Carnian sandstone; water), 1349.78 m (Intra-Carnian sandstone; gas), 1353.41 m (Intra-Carnian sandstone; gas), 1560.21 m (Kobbe Formation: gas), 1595.97 m (Kobbe Formation: only fluid scanning; no sample), 1778.65 m (Kobbe Formation: gas).The well was permanently abandoned on 25 September 2011 as a gas discovery.TestingThe well was perforated from 1557-1570 m,1580-1621 m and 1631 m-1685 m in the Kobbe interval.The test produced 180000 Sm3 gas/day througt a 44/64" choke. The gas gravity 0,618(air=1) -
Cuttings at the Norwegian Offshore Directorate
Cuttings at the Norwegian Offshore Directorate Cuttings available for sampling?YESCuttings at the Norwegian Offshore Directorate Cutting sample, top depth [m]Cutting samples, bottom depth [m]690.004149.00 -
Cores at the Norwegian Offshore Directorate
Cores at the Norwegian Offshore Directorate Core sample numberCore sample - top depthCore sample - bottom depthCore sample depth - uom11204.01256.9[m ]21675.01691.7[m ]32610.02637.1[m ]44013.04013.5[m ]Cores at the Norwegian Offshore Directorate Total core sample length [m]97.1Cores at the Norwegian Offshore Directorate Cores available for sampling?YES -
Casing and leak–off tests
Casing and leak–off tests Casing typeCasing diam.
[inch]Casing depth
[m]Hole diam.
[inch]Hole depth
[m]LOT/FIT mud eqv.
[g/cm3]Formation test typeCONDUCTOR30482.036484.00.00LOTSURF.COND.20665.026672.01.50LOTPILOT HOLE681.09 7/8681.00.00INTERM.13 5/81062.017 1/21070.01.82LOTINTERM.9 5/82503.012 1/42514.01.85LOTLINER73749.08 1/23750.01.90LOTOPEN HOLE4150.064150.00.00LOT -
Drill stem tests (DST)
Drill stem tests (DST) Test numberFrom depth MD
[m]To depth MD
[m]Choke size
[mm]1.01557168517.5Drill stem tests (DST) Test numberFinal shut-in pressure
[MPa]Final flow pressure
[MPa]Bottom hole pressure
[MPa]Downhole temperature
[°C]1.0Drill stem tests (DST) Test numberOil
[Sm3/day]Gas
[Sm3/day]Oil density
[g/cm3]Gas grav. rel.airGOR
[m3/m3]1.01800000.618 -
Logs
Logs Log typeLog top depth [m]Log bottom depth [m]FMI GR37504150FMI PPC MSIP PPC33904147HGNS CMR37504150IBC DCBL GR8002503LEH EDTC HNGS APS TLD HRLA CMR S25803745LEH EDTC PPC MSIP PPC FMI24253753LWD - ADR SWRO GM PWD PCDC40164150LWD - AFR EWR DGR ALD CTN FTWD P6771067LWD - EWR DGR PWD DI4403750LWD - EWR P4 DGR PWD PCDC37514013MDT GR10622064MDT GR15941889MDT GR15961976MDT GR26052640MDT GR26062606MDT GR26063472MDT GR26092620MSCT GR10902309MSCT GR10901826MSCT GR26053475MSIP FMI10622064SP CMR HRLA TLD APS HNGS10622064SP GPIT PPC MSIP PPC TLD APS HNG10622514SP HRLA TLD APS37504150USIT CBL GR3951062VSP GR4162514VSP GR25004143 -
Lithostratigraphy
Lithostratigraphy Top depth [mMD RKB]Lithostrat. unit4164166366706957277277708041146152215222155255536663666377139313931 -
Drilling mud
Drilling mud Depth MD [m]Mud weight [g/cm3]Visc. [mPa.s]Yield point [Pa]Mud typeDate measured4311.3010.0waterbased5001.3010.0waterbased5021.2411.0ManualEntry5111.3010.0waterbased5401.2513.0waterbased5521.0516.0seawater5521.2510.0waterbased6521.3010.0waterbased6801.0516.0waterbased8541.2512.0waterbased8541.3714.0waterbased9571.3514.0waterbased10701.2517.0waterbased17301.361.0brine20141.3519.0waterbased21001.4524.0waterbased25141.3522.0waterbased37501.5222.0waterbased41501.4517.0waterbased