30/9-16
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General information
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Wellbore history
GeneralWell 30/9-16 was drilled on the Bjørgvin Arch south of the Oseberg Fault block in the North Sea. The primary objective was to prove hydrocarbon accumulations in the Tarbert Formation and the “NORE” (lower Brent Group) reservoir. Secondary objective was to test the hydrocarbon potential in the Cook Formation and Statfjord Group reservoirs within closure.Operations and resultsWildcat well 30/9-16 was spudded with the semi-submersible installation West Vanguard on 14 June 1994 and drilled to TD at 3550 m in the Early Jurassic Eiriksson Formation. No significant problem was encountered in the operations. The well was drilled with spud mud down to 165 m, with ANCO 2000 mud from 165 m to 2668 m, and with KCl/polymer mud from 2668 m to TD.Intra Heather Formation sandstone came in at 2685 m and proved to be gas bearing with GOC at 2706 m, based on geochemical data. Based on RFT pressure gradients the GOC is at 2711 m. The Tarbert Formation came in at 2718 m and was 101 m thick, 11 m thicker than prognosed. It was oil-bearing with an OWC at 2764 m. There is a 10 bars pressure difference in the oil zone, between 30/9-13 S and 30/9-16. The 30/9-9 Lower Ness oil gradient is 14 bars higher than the 30/9-16 oil gradient. The water gradient is only 1.5 bars higher than 30/9-13 S and three bars lower than 30/9-9. No hydrocarbons or shows were reported below OWC in the Brent Group, but weak shows, with gas shows at the top and oil shows below, were reported from the Statfjord Group at 3455 – 3475 m. Further, down to TD, these shows disappeared or became localised.Four cores were cut. The three first were cut from 2694 m in the Heather Formation sandstone to 2796.4 m in the Tarbert Formation. Core 4 was cut from 3459 m to 3486.2 m in the upper part of the Statfjord Group. An RFT fluid sample was taken at 2727 m in the Tarbert Formation. It contained oil and water.The well was permanently abandoned on 8 August 1994 as an oil and gas discovery.TestingTwo drill stem tests were performed.DST 1 tested the interval 2722 - 2753 m in the Tarbert Formation. It produced 264000 Sm3 gas and 1600 Sm3 oil/day through a 72/64” choke. The GOR was 165 Sm3/Sm3, the oil density was 0.836 g/cc density, and the gas gravity was 0.733 (air = 1) with 2.1 % CO2 and 1.5 ppm H2S. The flowing bottom hole temperature was 106.6 °C.DST2 tested the interval 2685.1 - 2694.1 min the Intra-Heather Formation sandstone.It produced 722000 Sm3 gas and 238 Sm3 oil/day through a 64/64” choke. The GOR was 3030 Sm3/Sm3, the condensate density was 0.836 g/cc density, and the gas gravity was 0.733 (air = 1) with 2.1 % CO2 and 1.5 ppm H2S. The flowing bottom hole temperature was 106.6 °C.No water was produced in the tests. -
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]1590.003550.00 -
Cores at the Norwegian Offshore Directorate
Cores at the Norwegian Offshore Directorate Core sample numberCore sample - top depthCore sample - bottom depthCore sample depth - uom12694.02722.4[m ]22722.52759.7[m ]32759.72796.4[m ]43459.03486.2[m ]Cores at the Norwegian Offshore Directorate Total core sample length [m]129.4Cores at the Norwegian Offshore Directorate Cores available for sampling?YES -
Core photos
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Palynological slides at the Norwegian Offshore Directorate
Palynological slides at the Norwegian Offshore Directorate Sample depthDepth unitSample typeLaboratory1590.0[m]DCSPT1610.0[m]DCSPT1630.0[m]DCSPT1660.0[m]DCSPT1680.0[m]DCSPT1700.0[m]DCSPT1720.0[m]DCSPT1750.0[m]DCSPT1780.0[m]DCSPT1800.0[m]DCSPT1820.0[m]DCSPT1840.0[m]DCSPT1860.0[m]DCSPT1880.0[m]DCSPT1900.0[m]DCSPT1930.0[m]DCSPT1950.0[m]DCSPT1970.0[m]DCSPT1990.0[m]DCSPT2010.0[m]DCSPT2030.0[m]DCSPT2050.0[m]DCSPT2070.0[m]DCSPT2090.0[m]DCSPT2110.0[m]DCSPT2130.0[m]DCSPT2140.0[m]DCSPT2150.0[m]DCSPT2170.0[m]DCSPT2190.0[m]DCSPT2205.0[m]DCSPT2225.0[m]DCSPT2245.0[m]DCSPT2265.0[m]DCSPT2285.0[m]DCSPT2305.0[m]DCSPT2325.0[m]DCSPT2345.0[m]DCSPT2365.0[m]DCSPT2385.0[m]DCSPT2395.0[m]DCSPT2405.0[m]DCSPT2425.0[m]DCSPT2445.0[m]DCSPT2465.0[m]DCSPT2485.0[m]DCSPT2505.0[m]DCSPT2525.0[m]DCSPT2545.0[m]DCSPT2565.0[m]DCSPT2585.0[m]DCSPT2605.0[m]DCSPT2625.0[m]DCSPT2645.0[m]DCSPT2655.0[m]DCSPT2667.0[m]DCSPT2670.0[m]SWCSPT2672.5[m]SWCSPT2679.0[m]SWCSPT2682.0[m]SWCSPT2684.0[m]SWCSPT2695.7[m]CSPT2707.8[m]CSPT2720.8[m]DCSPT2739.0[m]CSPT2796.5[m]CSPT2798.0[m]SWCSPT2807.0[m]SWCSPT2813.0[m]SWCSPT2817.0[m]DCSPT2825.0[m]DCSPT2830.0[m]SWCSPT2839.0[m]SWCSPT2850.0[m]DCSPT2855.5[m]SWCSPT2862.0[m]DCSPT2870.0[m]DCSPT2880.0[m]SWCSPT2910.0[m]DCSPT2917.0[m]DCSPT2925.0[m]DCSPT2940.0[m]SWCSPT2955.0[m]SWCSPT2965.0[m]DCSPT2976.0[m]SWCSPT2992.0[m]SWCSPT2998.0[m]SWCSPT3010.0[m]DCSPT3016.0[m]SWCSPT3020.0[m]DCSPT3033.0[m]SWCSPT3040.0[m]DCSPT3050.0[m]DCSPT3056.0[m]SWCSPT3070.0[m]SWCSPT3080.0[m]DCSPT3080.0[m]SWCSPT3100.0[m]DCSPT3110.0[m]SWCSPT3120.0[m]DCSPT3130.0[m]SWCSPT3140.0[m]DCSPT3150.0[m]SWCSPT3160.0[m]DCSPT3170.0[m]SWCSPT3185.0[m]SWCSPT3190.0[m]DCSPT3203.0[m]SWCSPT3210.0[m]DCSPT3220.0[m]SWCSPT3230.0[m]DCSPT3240.0[m]SWCSPT3250.0[m]DCSPT3260.0[m]DCSPT3265.0[m]SWCSPT3280.0[m]SWCSPT3295.0[m]SWCSPT3305.0[m]DCSPT3315.0[m]SWCSPT3325.0[m]DCSPT3335.0[m]SWCSPT3345.0[m]DCSPT3355.0[m]SWCSPT3360.0[m]DCSPT3370.0[m]DCSPT3383.0[m]SWCSPT3400.0[m]DCSPT3412.0[m]DCSPT3420.0[m]DCSPT3430.0[m]DCSPT3440.0[m]DCSPT3450.0[m]DCSPT3459.0[m]CSPT3465.0[m]DCSPT3475.0[m]DCSPT3475.0[m]CSPT3481.0[m]CSPT3490.0[m]DCSPT3500.0[m]DCSPT3510.0[m]DCSPT3521.0[m]SWCSPT3533.0[m]SWCSPT3540.0[m]DCSPT3550.0[m]DCSPT -
Oil samples at the Norwegian Offshore Directorate
Oil samples at the Norwegian Offshore Directorate Test typeBottle numberTop depth
MD [m]Bottom depth
MD [m]Fluid typeTest timeSamples availableDSTDST12753.002722.00OIL23.04.1994 - 06:45YESDSTDST22694.102685.10OIL02.08.1994 - 12:00YES -
Lithostratigraphy
Lithostratigraphy Top depth [mMD RKB]Lithostrat. unit12363980080021202120217022252320238623862587262326232640264826522652267026852718271828202977298930013001307331403267345734573476 -
Geochemical information
Geochemical information Document nameDocument formatDocument size [MB]pdf0.37pdf0.47 -
Documents – reported by the production licence (period for duty of secrecy expired)
Documents – reported by the production licence (period for duty of secrecy expired) Document nameDocument formatDocument size [MB]pdf14.67pdf19.85 -
Drill stem tests (DST)
Drill stem tests (DST) Test numberFrom depth MD
[m]To depth MD
[m]Choke size
[mm]1.02722275328.62.02685269425.4Drill stem tests (DST) Test numberFinal shut-in pressure
[MPa]Final flow pressure
[MPa]Bottom hole pressure
[MPa]Downhole temperature
[°C]1.02.0Drill stem tests (DST) Test numberOil
[Sm3/day]Gas
[Sm3/day]Oil density
[g/cm3]Gas grav. rel.airGOR
[m3/m3]1.016042640000.8361652.02837220000.7503030 -
Logs
Logs Log typeLog top depth [m]Log bottom depth [m]CST29703550DLL LSS GP GR CAL AMS1233353FMI GR AMS26583352LDL CNL15783532NGT26583301NGT26583523RFT26882990RFT26882790RFT31853519VSP4603540 -
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 typeCONDUCTOR30207.036208.00.00SURF.COND.13 3/81578.017 1/21588.01.70LOTINTERM.9 5/82658.012 1/22668.01.60FITLINER72958.08 1/23550.00.00 -
Drilling mud
Drilling mud Depth MD [m]Mud weight [g/cm3]Visc. [mPa.s]Yield point [Pa]Mud typeDate measured1231.05WATER BASED14.06.19942081.05WATER BASED15.06.19944881.05WATER BASED17.06.199411551.05WATER BASED17.06.199415881.05WATER BASED20.06.199415881.05WATER BASED20.06.199419051.4330.013.0WATER BASED24.06.199422711.4329.017.0WATER BASED24.06.199423791.4329.016.5WATER BASED28.06.199425221.4328.015.5WATER BASED28.06.199426681.4326.015.0WATER BASED28.06.199426681.4327.014.5WATER BASED28.06.199426681.4327.014.5WATER BASED30.06.199426681.4524.016.0WATER BASED01.07.199426751.1312.09.5WATER BASED08.08.199426941.1220.012.5WATER BASED07.07.199427601.1416.010.0WATER BASED07.07.199428721.1415.011.5WATER BASED07.07.199428721.1415.011.5WATER BASED07.07.199429581.4314.010.0WATER BASED09.08.199429581.1415.010.5WATER BASED22.07.199429581.1320.012.0WATER BASED26.07.199429581.1415.011.5WATER BASED01.08.199429581.1312.09.5WATER BASED08.08.199429581.4315.08.5WATER BASED09.08.199429581.1320.012.0WATER BASED26.07.199429581.1320.012.0WATER BASED27.07.199429581.1320.012.0WATER BASED28.07.199429581.1318.013.0WATER BASED29.07.199429581.1315.012.5WATER BASED01.08.199429581.1313.011.0WATER BASED02.08.199429581.1313.011.5WATER BASED03.08.199429581.1321.016.5WATER BASED15.07.199429581.1314.013.5WATER BASED18.07.199429581.1314.013.5WATER BASED18.07.199429581.1314.014.0WATER BASED18.07.199429581.1313.013.5WATER BASED19.07.199429581.1313.013.5WATER BASED20.07.199429581.1415.010.5WATER BASED21.07.199429581.1311.011.0WATER BASED25.07.199429591.1320.012.0WATER BASED26.07.199430401.1219.011.0WATER BASED07.07.199430401.1219.011.0WATER BASED07.07.199432651.3023.021.0WATER BASED11.07.199432651.23213.017.0WATER BASED12.07.199434451.3022.016.5WATER BASED07.07.199434861.3024.021.0WATER BASED11.07.199435501.3024.021.0WATER BASED11.07.199435501.2320.011.0WATER BASED13.07.199435501.3024.021.0WATER BASED11.07.1994 -
Pressure plots
Pressure plots The pore pressure data is sourced from well logs if no other source is specified. In some wells where pore pressure logs do not exist, information from Drill stem tests and kicks have been used. The data has been reported to the NPD, and further processed and quality controlled by IHS Markit.Pressure plots Document nameDocument formatDocument size [MB]pdf0.23