6407/9-5
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General information
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Wellbore history
GeneralWell 6407/9-5 was the fifth well drilled on the Draugen Field in the southern Haltenbanken area. Wells 6407/9-1, 6407/9-2 and 6407/9-3 delineated an areally extensive oil accumulation in relatively thin Late Jurassic Rogn Formation sandstone. Net oil sand thicknesses in these wells were 39, 12 and 34 m respectively. The oil gravity was 40 deg API. Well 6407/9-4, located on the west flank of the northern accumulation, confirmed pinch out of the Rogn Formation and encountered similar oil in the underlying Garn formation. The initial conditions of pressure and oil water contact in this well (1638.5 m MSL were similar to those in the Rogn Formation accumulation. The objectives of well 6407/9-5 were to delineate top structure and rock qualities in the southern culmination. Prognosed TD was 1805 m in rocks of Triassic age, or a maximum depth of 4000 m.Operations and resultsAppraisal well 6407/9-5 was spudded with the semi-submersible installation West Venture on 12 September 1985 and drilled to TD at 1820 m in the Early Jurassic Not Formation. Drilling proceeded without serious problems, except for the sections trough glacial deposits were huge boulders caused minor problems. The well was drilled vertical. Deepest reported deviation survey was at 1675 m (1675 m TVD RKB). To this depth maximum deviation from vertical was 0.66 deg. The well was drilled with seawater and bentonite down to 811 m, with KCl/polymer mud from 811 m to 1625 m, and with chalk mud from 1625 m to TD.The Rogn Formation was encountered at 1654 m, 15 m deeper than prognosed. Light oil was discovered, as known from the other wells in the Draugen field. The oi1/water contact was found at 1671 m (1639 m MSL), the same contact as in the other wells drilled on the Draugen Field. Average reservoir quality over this 17 m interval was good, with a calculated hydrocarbon saturation of 76% and a porosity of 27%. Core permeabilities from the oil interval typically ranged between 1 and 10 Darcy. The base of the Rogn Formation, from 1704.0 - 1734.0 was laminated, bituminous shales with occasionally sandy and silty beds, which were strongly pyrite cemented. This interval forms a thick impermeable layer between the Rogn and the underlying Garn sands. The underlying water bearing Garn Formation contained 32 m of sandstone with 32 % average porosity. Oil shows were recorded only in the Rogn Formation reservoir from top and down to 1675 m. No shows were seen elsewhere in the well.Four cores were cut in the interval 1654 - 1703 m in the Rogn Formation. No fluid samples were acquired on wire line, although several attempts were made.On completion of the testing the well was suspended on 13 November 1985 as a possible future oil producer. It was re-entered in April 1993. It was taken in use as an oil producer and renamed 6407/9-A-55 H.TestingOne DST test was performed in the interval 1654 - 1661 m (1621 to 1628 m MSL).The well produced up to a maximum of 1210 Sm3 oil /day of 40 deg API oil through a 1" choke. Separator GOR was measured at 18.2 Sm3/Sm3. The gas gravity was 0.818 (air = 1) with 0.35% CO2 and 0 ppm H2S. Initial reservoir pressure was calculated as 2394 psia at 1663 m (1630 m MSL). The previously established Draugen reservoir pressure of 2392 psia (at datum) was within the accuracy of the gauges. -
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]420.001820.00 -
Cores at the Norwegian Offshore Directorate
Cores at the Norwegian Offshore Directorate Core sample numberCore sample - top depthCore sample - bottom depthCore sample depth - uom11654.31668.7[m ]21671.01672.9[m ]31674.01683.7[m ]41685.01701.4[m ]Cores at the Norwegian Offshore Directorate Total core sample length [m]42.4Cores 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 typeLaboratory1250.0[m]DCFUGRO1260.0[m]DCFUGRO1270.0[m]DCFUGRO1280.0[m]DCFUGRO1290.0[m]DCFUGRO1300.0[m]DCFUGRO1310.0[m]DCFUGRO1320.0[m]DCFUGRO1330.0[m]DCFUGRO1340.0[m]DCFUGRO1350.0[m]DCFUGRO1360.0[m]DCFUGRO1370.0[m]DCFUGRO1380.0[m]DCFUGRO1390.0[m]DCFUGRO1400.0[m]DCFUGRO1410.0[m]DCFUGRO1420.0[m]DCFUGRO1657.5[m]CAPT1660.8[m]CAPT1672.4[m]CAPT1674.3[m]CAPT1683.3[m]CAPT1699.7[m]CAPT1700.4[m]CAPT1700.7[m]CAPT1701.0[m]CAPT1701.4[m]CAPT -
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 availableDSTDST11654.001661.0030.10.1985 - 01:30YES -
Lithostratigraphy
Lithostratigraphy Top depth [mMD RKB]Lithostrat. unit319319670787787130513051347153015791619161916541705173317331793 -
Composite logs
Composite logs Document nameDocument formatDocument size [MB]pdf0.34 -
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]pdf5.16pdf0.92 -
Drill stem tests (DST)
Drill stem tests (DST) Test numberFrom depth MD
[m]To depth MD
[m]Choke size
[mm]1.01654166125.4Drill 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]1.01203230000.8250.78517 -
Logs
Logs Log typeLog top depth [m]Log bottom depth [m]CBL11931679CBL VDL11501680DLL MSFL GR16171811GR13001625GR15501604ISF LSS GR317810ISF LSS GR8031606ISF LSS GR16171815LDL CNL GR397811LDL CNL GR8031606LDL CNL NGS16171816RFT16171807RFT16581760RFT16581760SHDT16171810SWS11001605SWS16181807WST4891800 -
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 typeCONDUCTOR30396.036408.00.00LOTCONDUCTOR30408.036408.00.00LOTSURF.COND.20801.026811.01.52LOTINTERM.13 3/81617.017 1/21625.01.72LOTINTERM.9 5/81800.012 1/41820.00.00LOT -
Drilling mud
Drilling mud Depth MD [m]Mud weight [g/cm3]Visc. [mPa.s]Yield point [Pa]Mud typeDate measured4081.04120.0WATER BASED16.09.19854201.25WATER BASED11.11.19854201.25WATER BASED12.11.19855201.0460.0WATER BASED16.09.19858111.0980.0WATER BASED17.09.19858111.09120.0WATER BASED18.09.19858111.04120.0WATER BASED19.09.19858111.03WATER BASED20.09.19858111.03WATER BASED23.09.19859081.3547.026.0WATER BASED23.09.198512201.4050.027.0WATER BASED24.09.198512201.4024.024.0WATER BASED25.09.198515951.15WATER BASED07.11.198515951.15WATER BASED11.11.198516161.4020.021.0WATER BASED26.09.198516191.15WATER BASED05.11.198516191.15WATER BASED06.11.198516251.4021.022.0WATER BASED27.09.198516251.4022.023.0WATER BASED30.09.198516251.4023.023.0WATER BASED30.09.198516541.2016.024.0WATER BASED01.10.198516601.1947.027.0WATER BASED07.10.198516741.2021.028.0WATER BASED02.10.198516791.1818.022.0WATER BASED09.10.198516841.1813.014.0WATER BASED10.10.198516881.15WATER BASED14.10.198516881.15WATER BASED15.10.198516881.15WATER BASED16.10.198516881.15WATER BASED17.10.198516881.15WATER BASED18.10.198516881.15WATER BASED21.10.198516881.15WATER BASED22.10.198516881.15WATER BASED23.10.198516881.15WATER BASED24.10.198516881.15WATER BASED28.10.198516881.15WATER BASED29.10.198516881.15WATER BASED31.10.198516881.15WATER BASED04.11.198516881.15WATER BASED11.10.198516891.15WATER BASED14.10.198517031.2022.029.0WATER BASED03.10.198517881.1920.027.0WATER BASED08.10.198518201.2021.029.0WATER BASED04.10.198518201.2023.023.0WATER BASED07.10.1985 -
Thin sections at the Norwegian Offshore Directorate
Thin sections at the Norwegian Offshore Directorate DepthUnit1638.00[m ] -
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]PDF0.25