9/2-3
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General information
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Wellbore history
GeneralWell 9/2-3 is located ca 11.5 km southwest of the Yme Field in the Egersund Basin. The objectives of the well were to test the sandstones of Late/Middle Jurassic age, the Sandnes- and Bryne formations. Furthermore the 9/2-3 well will test the geophysical and structural interpretation of the area and improve the paleontological, geological and geochemical understanding of this area in the North Sea. A strong reflector was observed at 253 m, but was expected to be a change in lithology rather than shallow gas.Operations and resultsWildcat well 9/2-3 was spudded with the semi-submersible installation Vildkat Explorer 4 December 1989 on and drilled to TD at 3424 m in the Middle Jurassic Bryne Formation. No shallow gas was encountered in this well. Drilling went on without significant difficulties. The well was drilled with seawater/gel/bentonite down to 376 m, with gypsum/polymer mud from 376 m to 3210, and with a polymer/Resinex mud from 3210 m to TD.The Sandnes Formation was encountered at 3252 m and proved oil. The OWC was difficult to place from the logs, but was estimated at 3273 m. This gives a 21 m oil column. Gross reservoir interval was found to be 115 m. Core and log analysis indicate a fairly low porosity sandstone with small amounts of silt, shale and limestone (calcite cement). The Bryne Formation proved to be water bearing, and no test was performed in this formation.Organic geochemical analyses show that the Tau Formation (3098 m to 3188 m) is an excellent source rock with TOC in the range 3 to 13 % and hydrogen index in the range 360 to 700 mg HC/g TOC. The Tau Formation is early oil-window mature (%Ro around 0.6 and Tmax from 430 to 435 deg C) in the well. Analyses of the DST oil show a somewhat higher maturity than the in-well source rock. Furthermore, the oil showed a close resemblance to the 9/2-1 DST 3 oil.One conventional core was cut in the Sandnes formation in the interval 3264 to 3291 m. Sidewall cores were shot in two rounds with a total of 45 shots whereof 30 were recovered. One run with the FMT tool was made in the interval 3260 to 3329 m in the Sandnes/Bryne formations. Only 9 out of 64 attempts were successful and no fluid gradients could be evaluated from the pressure plot. One segregated sample was taken at 3263.1 m. The 2 3/4-gallon chamber contained mud and the 1-gallon chamber was empty due to plugging in the chamber line.The well was permanently abandoned on 8 February 1990 as an oil discovery.TestingOne DST test was performed in the interval 3258 to 3268 m. The Sandnes formation was confirmed oil bearing. The production rate was very low due to low permeability. Gas was not produced during the test, and 4 Sm3/d oil was produced through a 12,7 mm choke. The static bottom hole temperature measured in the test was 102.5 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]380.003420.00 -
Cores at the Norwegian Offshore Directorate
Cores at the Norwegian Offshore Directorate Core sample numberCore sample - top depthCore sample - bottom depthCore sample depth - uom13264.03292.3[m ]Cores at the Norwegian Offshore Directorate Total core sample length [m]28.3Cores 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 typeLaboratory400.0[m]DCHALIB420.0[m]DCHALIB440.0[m]DCHALIB460.0[m]DCHALIB480.0[m]DCHALIB500.0[m]DCHALIB520.0[m]DCHALIB540.0[m]DCHALIB560.0[m]DCHALIB580.0[m]DCHALIB600.0[m]DCHALIB620.0[m]DCHALIB640.0[m]DCHALIB660.0[m]DCHALIB680.0[m]DCHALIB700.0[m]DCHALIB720.0[m]DCHALIB760.0[m]DCHALIB780.0[m]DCHALIB800.0[m]DCHALIB840.0[m]DCHALIB860.0[m]DCHALIB880.0[m]DCHALIB900.0[m]DCHALIB920.0[m]DCHALIB940.0[m]DCHALIB950.0[m]DCHALIB960.0[m]DCHALIB970.0[m]DCHALIB980.0[m]DCHALIB990.0[m]DCHALIB1000.0[m]DCHALIB1020.0[m]DCHALIB1030.0[m]DCHALIB1040.0[m]DCHALIB1050.0[m]DCHALIB1900.0[m]DCHALIB1920.0[m]DCHALIB1930.0[m]DCHALIB1940.0[m]DCHALIB1950.0[m]DCHALIB1960.0[m]DCHALIB1970.0[m]DCHALIB1985.0[m]DCHALIB2000.0[m]DCHALIB2015.0[m]DCHALIB2030.0[m]DCHALIB2045.0[m]DCHALIB2060.0[m]DCHALIB2075.0[m]DCHALIB2105.0[m]DCHALIB2120.0[m]DCHALIB2135.0[m]DCHALIB2150.0[m]DCHALIB2195.0[m]DCHALIB2240.0[m]DCHALIB2255.0[m]DCHALIB2270.0[m]DCHALIB2285.0[m]DCHALIB2300.0[m]DCHALIB2315.0[m]DCHALIB2330.0[m]DCHALIB2345.0[m]DCHALIB2360.0[m]DCHALIB2375.0[m]DCHALIB2390.0[m]DCHALIB2405.0[m]DCHALIB2420.0[m]DCHALIB2430.0[m]DCHALIB2440.0[m]SWCSTATO2455.0[m]DCHALIB2470.0[m]SWCSTATO2485.0[m]DCHALIB2495.0[m]SWCSTATO2505.0[m]SWCSTATO2525.0[m]SWCSTATO2535.0[m]SWCSTATO2555.0[m]DCHALIB2570.0[m]DCHALIB2585.0[m]DCHALIB2600.0[m]DCHALIB2615.0[m]DCHALIB2630.0[m]DCHALIB2645.0[m]DCHALIB2660.0[m]DCHALIB2675.0[m]DCHALIB2690.0[m]DCHALIB2705.0[m]DCHALIB2720.0[m]DCHALIB2735.0[m]DCHALIB2750.0[m]DCHALIB2765.0[m]DCHALIB2780.0[m]DCHALIB2795.0[m]DCHALIB2810.0[m]DCHALIB2825.0[m]DCHALIB2840.0[m]DCHALIB2855.0[m]DCHALIB2870.0[m]DCHALIB2885.0[m]DCHALIB2900.0[m]DCHALIB2915.0[m]DCHALIB2930.0[m]DCHALIB2945.0[m]DCHALIB2960.0[m]DCHALIB2975.0[m]DCHALIB2990.0[m]DCHALIB3005.0[m]DCHALIB3020.0[m]DCHALIB3035.0[m]DCHALIB3050.0[m]DCHALIB3065.0[m]DCHALIB3080.0[m]DCHALIB3090.0[m]DCHALIB3094.0[m]SWCSTATO3100.0[m]DCHALIB3108.0[m]SWCSTATO3122.0[m]SWCSTATO3131.0[m]SWCSTATO3143.0[m]SWCSTATO3155.0[m]DCHALIB3170.0[m]DCHALIB3185.0[m]DCHALIB3200.0[m]DCHALIB3251.0[m]SWCSTATO3255.5[m]CSTATO3264.2[m]CSTATO3265.9[m]CSTATO3270.8[m]CSTATO3274.0[m]CSTATO3278.5[m]CSTATO3281.3[m]CSTATO3290.0[m]CSTATO3290.9[m]CSTATO3305.0[m]SWCSTATO3330.0[m]DCHALIB3341.0[m]SWCSTATO3345.0[m]SWCSTATO3360.0[m]DCHALIB3375.0[m]DCHALIB3390.0[m]DCHALIB -
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 availableDSTTEST13258.003268.0029.01.1990 - 05:55YES -
Lithostratigraphy
Lithostratigraphy Top depth [mMD RKB]Lithostrat. unit104410938938963986102510311031113914231867191119111932202726252625279930983188325232523373 -
Composite logs
Composite logs Document nameDocument formatDocument size [MB]pdf0.40 -
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]pdf20.47 -
Drill stem tests (DST)
Drill stem tests (DST) Test numberFrom depth MD
[m]To depth MD
[m]Choke size
[mm]1.03258326812.7Drill 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]1.04 -
Logs
Logs Log typeLog top depth [m]Log bottom depth [m]ACBL VDL GR2751106ACBL VDL GR31943396CDL CNL GR31923404DIFL ACL GR11063182DIFL ACL GR31923397DIPLOG31953358FMT32603329MWD - GR RES DIR1663422SWC GR24403143SWC GR32343349VELOCITY4903190 -
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 typeCONDUCTOR30163.036169.00.00LOTINTERM.20350.026375.01.39LOTINTERM.13 3/81106.017 1/21121.02.04LOTINTERM.9 5/83195.012 1/43210.01.87LOTLINER73424.08 1/23424.00.00LOT -
Drilling mud
Drilling mud Depth MD [m]Mud weight [g/cm3]Visc. [mPa.s]Yield point [Pa]Mud typeDate measured11211.1020.06.0WATER BASED11.12.198911211.1417.03.5WATER BASED12.12.198912721.1527.04.5WATER BASED14.12.198914811.1617.03.5WATER BASED14.12.198916181.1320.04.5WATER BASED19.12.198916181.1319.04.0WATER BASED19.12.198916181.1316.03.5WATER BASED19.12.198916181.1320.05.0WATER BASED19.12.198916961.1320.05.0WATER BASED21.12.198917921.1320.04.5WATER BASED21.12.198919411.1419.04.5WATER BASED22.12.198921701.1417.04.5WATER BASED28.12.198925111.1418.04.5WATER BASED28.12.198927201.1414.03.5WATER BASED28.12.198927531.2017.03.5WATER BASED28.12.198931451.3329.05.0WATER BASED28.12.198931451.3331.05.0WATER BASED29.12.198931451.3532.05.0WATER BASED03.01.199031451.3528.05.5WATER BASED03.01.199032101.4829.05.5WATER BASED03.01.199032101.2620.04.0WATER BASED05.01.199032101.2623.05.0WATER BASED05.01.199032101.2622.03.5WATER BASED08.01.199032101.2622.05.0WATER BASED08.01.199032101.2625.05.5WATER BASED09.01.199032101.2624.05.5WATER BASED09.01.199032101.2630.07.0WATER BASED10.01.199032101.6336.06.5WATER BASED16.01.199032581.6336.05.0WATER BASED19.01.199032581.6342.05.0WATER BASED23.01.199032581.6326.03.5WATER BASED25.01.199032581.6331.04.0WATER BASED23.01.199032581.6333.04.5WATER BASED23.01.199032581.6328.04.0WATER BASED23.01.199032581.6327.04.0WATER BASED24.01.1990 -
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