6406/3-3
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General information
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Wellbore history
GeneralWell 6406/3-3 was drilled to appraise the southern part of the Beta structure, named Smørbukk South. This well was the fourth well on Smørbukk South, and it was a joint well between licenses PL 091 and PL 094. The primary target for the well was sandstones in the Middle-Early Jurassic age Halten Group (present nomenclature: Fangst and Båt Groups). The well location was chosen so that the Tomma I Formation (Garn Formation) was expected to be hydrocarbon bearing with hydrocarbon/water contacts in the Tomma III - Aldra Formations (Ile - Tilje Formations).Operations and resultsAppraisal well 6406/3-3 was spudded with the semi-submersible installation Dyvi Delta on 4 August 1986 and drilled to TD at 4416 m in the Early Jurassic Åre Formation. Operations went without significant incidents and were finished twenty days ahead of schedule. Only 5.2% rig time was registered as down time. The well was drilled with seawater/hi-vis pills/bentonite down to 1070 m, with gypsum/polymer mud from 1070 m to 2320 m, with gypsum/lignosulphonate/lignite mud from 2320 m to 3936 m, and with lignosulphonate/lignite/Anco resin mud from 3936 m to TD.The top of the reservoir came in at 3933 m, 49 m deeper than prognosed. Cores showed poor - medium visible porosity and good to poor oil shows from the top and down to ca 3955 m (ca 3925 m TVD MSL). The oil/water contact was thus almost 65 m higher than the other holes in the Beta structure. RFT-data indicated that the rest of the Fangst and Båt Groups contained water. Weak shows were however recorded on sidewall cores in the interval 4210 m to 4262 m in the Ti1je Formation, while weak shows were recorded on well site cuttings all through Middle - Early Jurassic down to TD.A fixed offset VSP with the source 2.6 km north of the location was shot in order to explain the surprising and negative results of the well. The VSP sections indicated a probably sealing, east-west striking fault at reservoir level approximately 1 km north of the well. Results of well 6406/3-3 indicated that the Beta structure was divided into segments bounded by minor fault trends. As a result the reserve estimates on the Beta structure were reduced by ca 33%.Two cores were cut in the intervals 3938 - 3952.5 and 3956 - 3972.2 m in the Garn Formation. No fluid samples were taken on wire line.The well was permanently abandoned on 26 October 1986 as a well with shows.TestingTwo DSTs were performed in the Garn Formation in this well. DST 1 at 4003 - 4012 m produced 35 m3 water/day on a 64/64" choke. The maximum temperature measured during the test was 136 deg C. DST 2 at 3940 - 3950 m gave no flow from a tight formation. Maximum temperature measured during DST 2 was 124 deg C. -
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]460.004416.00 -
Cores at the Norwegian Offshore Directorate
Cores at the Norwegian Offshore Directorate Core sample numberCore sample - top depthCore sample - bottom depthCore sample depth - uom13938.03952.5[m ]23956.03972.2[m ]Cores at the Norwegian Offshore Directorate Total core sample length [m]30.7Cores 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 typeLaboratory3591.0[m]DCPALEO3603.0[m]DCPALEO3618.0[m]DCPALEO3633.0[m]DCPALEO3648.0[m]DCPALEO3660.0[m]DCPALEO3675.0[m]DCPALEO3690.0[m]DCPALEO3705.0[m]DCPALEO3720.0[m]DCPALEO3732.0[m]DCPALEO3744.0[m]DCPALEO3759.0[m]DCPALEO3774.0[m]DCPALEO3789.0[m]DCPALEO3804.0[m]DCPALEO3819.0[m]DCPALEO3831.0[m]DCPALEO3846.0[m]DCPALEO3861.0[m]DCPALEO3867.0[m]DCPALEO3876.0[m]DCPALEO3891.0[m]DCPALEO3906.0[m]DCPALEO3921.0[m]DCPALEO3936.0[m]DCPALEO3942.4[m]CPALEO3947.9[m]CPALEO3951.0[m]DCPALEO3966.0[m]DCPALEO3969.6[m]CPALEO3974.0[m]SWCPALEO3981.0[m]DCPALEO3996.0[m]DCPALEO4011.0[m]DCPALEO4022.0[m]SWCPALEO4026.0[m]DCPALEO4037.0[m]SWCPALEO4041.0[m]DCPALEO4056.0[m]DCPALEO4068.0[m]DCPALEO4083.0[m]DCPALEO4095.6[m]SWCPALEO4098.0[m]DCPALEO4113.0[m]DCPALEO4128.0[m]DCPALEO4133.8[m]SWCPALEO4143.0[m]DCPALEO4151.7[m]SWCPALEO4161.0[m]DCPALEO4174.8[m]SWCPALEO4176.0[m]DCPALEO4190.3[m]SWCPALEO4191.0[m]DCPALEO4201.4[m]SWCPALEO4206.0[m]DCPALEO4209.6[m]SWCPALEO4215.0[m]DCPALEO4217.6[m]SWCPALEO4236.0[m]DCPALEO4246.6[m]SWCPALEO4251.0[m]DCPALEO4262.3[m]DCPALEO4266.0[m]DCPALEO4266.8[m]SWCPALEO4281.0[m]DCPALEO4296.0[m]DCPALEO4300.8[m]SWCPALEO4311.0[m]DCPALEO4316.5[m]SWCPALEO4326.0[m]DCPALEO4328.8[m]SWCPALEO4341.0[m]DCPALEO4347.1[m]SWCPALEO4356.0[m]DCPALEO4371.0[m]DCPALEO4386.0[m]DCPALEO4387.8[m]SWCPALEO4401.0[m]DCPALEO4403.3[m]SWCPALEO4407.8[m]SWCPALEO4413.8[m]SWCPALEO4416.0[m]DCPALEO -
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 availableDSTRFT2D3994.500.0029.09.1986 - 00:00YES -
Lithostratigraphy
Lithostratigraphy Top depth [mMD RKB]Lithostrat. unit331139019871987225622562307236831883188322238003800384339393939403840664131413142024404 -
Geochemical information
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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]pdf6.38pdf5.59pdf2.96 -
Logs
Logs Log typeLog top depth [m]Log bottom depth [m]CBL VDL CCL GR22493919CNL GR39524398CST GR39744413DLL GR39214416ISF LSS MSFL GR23014417LDL CNL GR23014419MWD - EWR GR39254347MWD - GR RES DIR04317RFT GR31933218RFT GR39403964RFT GR39524398RFT GR39944286SHDT GR39214420TEMP02300VELOCITY10004000 -
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 typeCONDUCTOR30442.036444.00.00LOTSURF.COND.201064.0261083.01.67LOTINTERM.13 3/82301.017 1/22536.01.99LOTINTERM.9 5/83918.012 1/43936.01.89LOTLINER74415.08 1/24416.00.00LOT -
Drilling mud
Drilling mud Depth MD [m]Mud weight [g/cm3]Visc. [mPa.s]Yield point [Pa]Mud typeDate measured4441.0435.015.4WATERBASED06.08.19864461.1237.019.6WATERBASED07.08.19867571.1242.023.1WATERBASED08.08.19868861.1632.04.9WATER BASED24.10.198610671.1240.028.0WATERBASED11.08.198610670.0041.030.8WATERBASED11.08.198610670.0037.026.6WATERBASED11.08.198610831.3039.014.0WATERBASED12.08.198610830.0042.013.3WATERBASED13.08.198610830.0051.09.8WATERBASED14.08.198610861.1243.09.7WATERBASED18.08.198611551.5557.07.7WATER BASED23.10.198611801.1242.010.0WATERBASED18.08.198613301.1243.010.0WATERBASED18.08.198616451.2051.013.0WATERBASED18.08.198619701.2553.014.0WATERBASED18.08.198623201.5262.014.0WATERBASED19.08.198623200.0066.014.0WATERBASED20.08.198623200.0070.013.3WATERBASED21.08.198625361.5554.08.4WATERBASED22.08.198627011.6865.018.2WATERBASED25.08.198628661.6858.012.0WATERBASED25.08.198629341.6865.013.3WATERBASED25.08.198629701.6862.011.9WATERBASED26.08.198630561.6853.09.8WATERBASED27.08.198630931.6865.011.2WATERBASED28.08.198631381.6859.010.5WATERBASED29.08.198631891.6850.09.1WATERBASED01.09.198632051.6851.09.8WATERBASED01.09.198632591.6855.010.5WATERBASED01.09.198632811.6858.09.8WATERBASED02.09.198633491.7155.09.1WATERBASED04.09.198634181.7158.010.5WATERBASED04.09.198634881.7153.019.5WATERBASED05.09.198635221.7153.010.0WATERBASED08.09.198635661.7156.010.0WATERBASED08.09.198636391.7570.03.5WATER BASED21.10.198636391.7557.03.5WATER BASED23.10.198636491.7153.09.0WATERBASED08.09.198637011.2545.02.8WATER BASED20.10.198637241.7153.09.8WATERBASED09.09.198637721.7156.09.8WATERBASED10.09.198637970.0048.08.4WATERBASED18.09.198637971.7553.011.2WATER BASED15.09.198637970.0052.011.2WATERBASED15.09.198637970.0032.011.2WATERBASED16.09.198637970.0058.010.5WATERBASED17.09.198638121.7560.011.2WATERBASED11.09.198638351.7558.011.2WATERBASED12.09.198638841.7555.09.8WATERBASED15.09.198639361.7553.011.2WATERBASED19.09.198639360.0060.012.6WATERBASED22.09.198639371.2550.07.7WATERBASED22.09.198639741.2560.07.0WATERBASED22.09.198639951.2651.03.5WATER BASED16.10.198639951.2555.02.8WATER BASED17.10.198639951.2550.02.8WATER BASED20.10.198639951.2555.02.8WATER BASED20.10.198640001.2550.03.5WATER BASED15.10.198640261.2558.07.7WATERBASED23.09.198641531.2550.06.3WATERBASED24.09.198641931.2557.06.3WATERBASED25.09.198643531.2560.06.3WATERBASED26.09.198643781.2555.05.6WATERBASED06.10.198643781.2560.06.3WATER BASED06.10.198643781.2550.05.6WATER BASED07.10.198643781.2548.04.9WATER BASED10.10.198643781.2554.07.0WATER BASED13.10.198643781.2552.03.5WATER BASED14.10.198643781.2549.04.9WATER BASED09.10.198643781.2555.03.5WATER BASED13.10.198644161.2557.05.6WATERBASED29.09.198644160.00125.07.7WATERBASED30.09.198644160.0090.05.6WATERBASED03.10.198644160.0090.05.6WATERBASED06.10.198644160.0070.06.3WATERBASED29.09.198644160.0075.07.0WATERBASED29.09.198644160.00130.07.0WATERBASED01.10.198644160.00119.07.0WATERBASED02.10.198644160.0070.05.7WATERBASED06.10.1986 -
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]PDF0.22