General information Attribute Value Wellbore nameOfficial name of wellbore based on NPD guidelines for designation of wells and wellbores.30/9-4 S TypeWellbore type. Legal values: EXPLORATION, DEVELOPMENT, OTHER (see 'Purpose' for more information)EXPLORATION PurposeFinal classification of the wellbore.
Legal values for exploration wellbores:
WILDCAT, APPRAISAL, WILDCAT-CCS, APPRAISAL-CCS.
Legal values for development wellbores:
OBSERVATION, PRODUCTION, INJECTION, INJECTION-CCS, OBSERVATION-CCS.
Legal values for other wellbores:
SOIL DRILLING (drilling in connection with track surveys and other subsurface surveys to investigate the soil conditions prior to placement of facilities),
SHALLOW GAS (drilling to investigate shallow gas before the first 'real' drilling on the location),
PILOT (drilling to investigate the geology and fluid connectors for location of the main wellbore),
SCIENTIFIC (drilling according to Law of Scientific research and exploration),
STRATIGRAPHIC (driling according to Law of Petroleum activities §2-1).WILDCAT
StatusStatus for the wellbore. Legal values are:
BLOWOUT: A blowout has occurred in the well.
CLOSED: A development wellbore that has been closed in a shorter or longer periode. Also applies to development wellbores where drilling is completed, but production/injection has not yet been reported.
DRILLING: The well is in the drilling phase - can be active drilling, logging, testing or plugging,
JUNKED: The drilling operation has been terminated due to technical problems.
P&A: Exploration: The well is plugged and abandoned, and can not be reentered for further use. Development wells: The production/injection from/to the well is stopped and the well is plugged. The wellhead is removed or else made unavailable for further well operations.
PLUGGED: The wellbore has been plugged, but the upper parts of the wellbore can be re-used. A sidetrack might be drilled at a later stage.
PRODUCING: It was produced from the wellbore at the time of the operators last monthly report to the NPD.
INJECTING: It was injected to the wellbore at the time of the operators last monthly report to the NPD.
PREDRILLED: The upper part of the well has been drilled, usually as part of a batch-drilling campaign covering several wellbores.
RE-CLASS TO DEV: Exploration wellbore that is reclassified to a development wellbore.
RE-CLASS TO TEST: Exploration wellbore that is reclassified to test production.
SUSPENDED: The drilling operation in the wellbore has been temporarily stopped. The current plan is to continue drilling later on.
P&AFactmaps in new window
Main areaName of the area on the Norwegian Continental Shelf where the wellbore is located. Legal values: BARENTS SEA, NORWEGIAN SEA, NORTH SEA.NORTH SEA FieldName of the field the wellbore is related to. DiscoveryName of the discovery the wellbore is related to. Well nameOfficial name of the parent well for the wellbore based on NPD guidelines for designation of wells and wellbores.30/9-4 Seismic locationPosition of spud location on seismic survey lines. SP: shotpoint.NH 82-064 SP. 444 Production licenceOfficial designation of the production licence the wellbore was drilled or planned to be drilled from ( well head posistion). Drilling operatorName of the licensee starting the drilling operation on behalf of the active production license (well head position). This will usually equal the operator of the production license.Norsk Hydro Produksjon AS Drill permitThe drilling permit number together with the version of the drilling permit as stated in the drilling permit granted by the NPD.444-L Drilling facilityNPD's name of the facility which the wellbore was drilled from. Drilling daysNumber of days from wellbore entry to wellbore completion.129 Entered dateThe date when he wellbore was spudded. For sidetracks: The date when new formation was drilled by kicking off from the mother-wellbore,22.11.1984 Completed dateExploration wellbores from moveable facilities:
For floating facilities - date when anchor handling is started. For jackups - date the jacking-down started. Exploration wellbores from fixed facilities and all development wellbores:
Date when the wellbore is at total depth, and last casing, liner or screen is set. In case of immediate plugging of the wellbore, completed date equals the date the last plug i set in the wellbore.
Date when the wellbore is at total depth, and last casing, liner or screen is set. In case of immediate plugging of the wellbore, completed date equals the date the last plug i set in the wellbore.
Release dateDate when raw data which has been reported to the authorities from the wellbore is not confidential any longer. Normally 2 years after finishing the drilling. May be earlier if the area of the production license is relinquished.30.03.1987 Publication dateDate quality control of the wellbore information was completed, so it can be published on the internet as a 'Well Data Summary Sheet' wellbore with more information available than other wellbores.07.01.2015 Purpose - plannedPre-drill purpose of the wellbore. Legal values for exploration wellbores: WILDCAT, APPRAISAL, WILDCAT-CCS, APPRAISAL-CCS. Example of legal values for development wellbores: OBSERVATION, PRODUCTION, INJECTION.WILDCAT ReentryStatus whether the wellbore has been re-entered (YES) or not (NO). Re-entered wellbores are not included in the count when wellbores are presented in statistical overviews.NO ContentFor exploration wellbores, status of discovery.
DRY, SHOWS (trace amounts of hydrocarbons), GAS, GAS/CONDENSATE, OIL or OIL/GAS.
SHOWS (GAS SHOWS, OIL SHOWS or OIL/GAS SHOWS) are detected as fluorescent cut (organic extract), petroleum odour, or visual stain on cuttings or cores, or as increased gas reading on the mud-loggers gas detection equipment.
Legal values for WILDCAT-CCS and APPRAISAL-CCS: WATER
For development wellbores, type of produced/injected fluid.
WATER, CUTTINGS, NOT AVAILABLE, OIL, GAS/CONDENSATE, OIL/GAS, CO2, GAS, WATER/GAS, NOT APPLICABLE.OIL/GAS
Discovery wellboreIndicator which tells if the wellbore made a new discovery. Legal values: YES, NO. Prior to press-release or other information regarding drilling results, the indicator will be “NO” as a default.YES 1st level with HC, ageAge of lithostratigraphic unit, 1st level, where hydrocarbons were encountered. Examples of legal values: CRETACEOUS, EARLY CRETACEOUS, LATE JURASSIC, EOCENE. See also NPD bulletins.MIDDLE JURASSIC 1st level with HC, formationName of lithostartigraphic unit, 1st level, where hydrocarbons were encountered. Shown only for released wells. Examples of legal values: BASEMENT, COOK FM, EKOFISK FM, HEIMDAL FM, SANDNES FM, SOGNEFJORD FM, TARBERT FM, BRENT GP. See also NPD bulletins.BRENT GP Kelly bushing elevation [m]Elevation of the rotary kelly bushing (RKB) above mean sea level.25.0 Water depth [m]Depth in metres betweem mean sea level and sea floor.110.0 Total depth (MD) [m RKB]Total measured length of wellbore from kelly bushing to total depth (driller's depth).4303.0 Final vertical depth (TVD) [m RKB]Vertical elevation from total depth to kelly bushing. Shown only for released wells. Referred to as true vertical depth (TVD).3577.0 Maximum inclination [°]Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.43.4 Bottom hole temperature [°C]Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.111 Oldest penetrated ageAge (according to Geologic Time Scale 2004 by F. M. Gradstein, et al. (2004)) of the oldest penetrated formation. May differ from age at TD for example in deviated wellbores. Examples of legal values: CRETACEOUS, EARLY CRETACEOUS, LATE JURASSIC, EARLY PERMIAN, EARLY TRIASSIC, EOCENE.EARLY JURASSIC Oldest penetrated formationName of the oldest lithostratigraphic unit penetrated by the wellbore. Shown only for released wells. In most wellbores this is formation or group at total depth. May differ from formation or group at TD for example in wellbores drilled with high deviation or through faults. Examples of legal values: AMUNDSEN FM, BALDER FM, BASEMENT, BLODØKS FM, BRYNE FM, BURTON FM, COOK FM, DRAKE FM, DRAUPNE FM, EKOFISK FM, DUNLIN GP.EIRIKSSON FM Geodetic datumReference system for coordinates. Example of legal values: ED50.ED50 NS degreesGeographic coordinate of the wellhead, north-south degrees.60° 28' 12.83'' N EW degreesGeographic coordinate of the wellhead, east-west degrees.2° 45' 32.05'' E NS UTM [m]Universal Transverse Mercator coordinate of the wellhead, north-south.6703963.61 EW UTM [m]Universal Transverse Mercator coordinate of the wellhead, east-west.486742.81 UTM zoneUniversal Transverse Mercator zone. Examples of legal values: 31, 32, 33, 34.31 NPDID wellboreNPD's unique id for the wellbore.452
Wellbore historyGeneralWell 30/9-4 S was drilled on the B-structure on the southeast flank of the Oseberg Field in the North Sea. The structure is an elongated rotated fault block bounded by faults in all directions. The Brent Group is truncated by the Base Cretaceous unconformity, and this well was expected to go directly from Cretaceous to the Ness formation. The objectives of the well were to find hydrocarbon accumulations in the Brent Group, secondary in the Statfjord Group. The well was designed to penetrate the Brent Group in a position where the sand in the Ness Formation is preserved. The well was deviated westwards at an angle of approximately 40°.Operations and resultsWildcat well 30/9-4 S was spudded with the semi-submersible installation Treasure Seeker on 22 November 1984 and drilled to TD at 4303 m (3577 m TVD) in the Early Jurassic Eiriksson Formation. No significant problems were encountered during operations. The well was drilled with spud mud down to 222 m, with seawater/gel from 222 m to 630 m, with oil based Safemul mud from 630 m to 3297 m, with NaCl/polymer mud from 3297 m to 3680 m, and with oil based Safemul mud from 3680 m to TD.The well 30/9-4 encountered two separate hydrocarbon reservoirs in the Middle Jurassic Brent Group. Pressure data indicated no communication between the two hydrocarbon columns. The Tarbert Formation and uppermost Ness Formation (3295-3379 m, 2773-2841 m TVD) sandstones were found to be gas bearing, but no definite gas/fluid contacts were evident. Net pay in the gas zone was calculated to be 27.6 m (22.1 m TVD), average porosity 18.6%, and the average water saturation 20.9%. The Ness Formation (3379-3551 m, 2841-2979 m TVD) proved to be oil bearing, but again no OWC could be discerned. Net pay in the oil zone was calculated to be 10.9 m (8.8 m TVD), average porosity to 22.2% and the average water saturation to 33.2%. The Statfjord Group was water bearing. No oil shows were reported above or below the hydrocarbon bearing Brent reservoir sands.Thirteen conventional cores were cut in the well. Cores no. 1-3 (3332 - 3381 m) and 4-11 (3432-3500 m) were cut in the gas bearing and oil bearing Brent Group sections, respectively. Core no. 12 (3580-3598.1 m) was cut in the Oseberg Formation and core no. 13 (4268-4277 m) was cut in the Eiriksson Formation. RFT fluid samples were taken in the Brent Group at 3319.5 m (oil and gas), 3421 m (condensate and gas), and in the top of the water bearing Statfjord Group at 4207.2 m.The well was permanently abandoned on 30 March 1985 as an oil and gas discovery.TestingTwo drill stem tests were performed in the Brent Group.DST 1 tested the interval 3416.9 to 3422.9 m (2871.4 m to 2876.1 m TVD) in the oil bearing part of the Ness Formation. The well produced 783.2 Sm3 oil and 158600 Sm3 gas/day through a 72/64" choke. The GOR was 202.5 Sm3/Sm3. The oil gravity was 41.8 °API and the gas gravity was 0.8 (air=l). The bottom hole temperature was 111.1°C. The test produced 2.2% C02 and no H2S.DST 2 tested the interval 3311.3 to 3324.3 m (2787 to 2797.7 m TVD) in the gas bearing Tarbert Formation. It produced 1130000 Sm3 gas and 333.9 Sm3 condensate/day through a 64/64" choke. The GOR was 3384.3 Sm3/Sm3. The oil gravity was 55.7 °API and the gas gravity was 0.7 (air=l). The bottom hole temperature was 108.3°C. The test produced 1.5% C02 and 0.8 ppm H2S.
Cuttings at the NPD
Cuttings at the NPDCuttings available for sampling?YES Cuttings at the NPDCutting sample, top depth [m]Cutting samples, bottom depth [m]230.004300.00
Cores at the NPD
Cores at the NPDCore sample numberCore sample - top depthCore sample - bottom depthCore sample depth - uom13332.03350.3[m ]23350.63368.0[m ]33368.63379.0[m ]43432.43436.0[m ]53437.03444.5[m ]63445.03466.2[m ]73457.03462.7[m ]83467.03469.6[m ]93472.03474.7[m ]103475.03483.8[m ]113484.03498.1[m ]123580.03598.0[m ]134268.04276.3[m ] Cores at the NPDTotal core sample length [m]126.5 Cores at the NPDCores available for sampling?YES
Palynological slides at the NPD
Palynological slides at the NPDSample depthDepth unitSample typeLaboratory2550.0[m]DCRRI2565.0[m]DCRRI3232.0[m]DCRRI3252.0[m]DCRRI3315.0[m]DCRRI3330.0[m]DCRRI3345.0[m]DCRRI3364.2[m]CRRI3395.0[m]DCRRI3412.0[m]DCRRI3417.0[m]DCRRI3432.0[m]DCRRI3432.6[m]CRRI3443.1[m]CRRI3452.8[m]CRRI3458.6[m]CRRI3467.8[m]CRRI3480.8[m]CRRI3498.1[m]CRRI3510.0[m]DCRRI3525.0[m]DCRRI3540.0[m]DCRRI3555.0[m]DCRRI3570.0[m]DCRRI3634.0[m]SWCRRI3665.0[m]DCRRI3680.0[m]DCRRI3935.0[m]DCRRI3950.0[m]DCRRI3960.0[m]DCRRI3974.0[m]SWCRRI3977.0[m]DCRRI3990.0[m]DCRRI4003.0[m]SWCRRI4005.0[m]DCRRI4020.0[m]DCRRI4025.0[m]SWCRRI4035.0[m]DCRRI4045.0[m]SWCRRI4050.0[m]SWCRRI4050.0[m]DCRRI4064.0[m]SWCRRI4065.0[m]DCRRI4080.0[m]SWCRRI4080.0[m]DCRRI4082.0[m]DCRRI4088.0[m]SWCRRI4097.0[m]DCRRI4115.0[m]SWCRRI4130.0[m]SWCRRI4139.0[m]SWCRRI4149.0[m]SWCRRI4162.0[m]SWCRRI4174.5[m]SWCRRI4268.3[m]CRRI4276.5[m]CRRI4287.0[m]DCRRI4292.0[m]SWCRRI4302.0[m]SWCRRI
Oil samples at the NPD
Oil samples at the NPDTest typeBottle numberTop depth
MD [m]Bottom depth
MD [m]Fluid typeTest timeSamples availableDSTDST13422.003416.00OIL11.03.1985 - 00:00YESDSTDST23324.003311.00CONDENSATE20.03.1985 - 00:00YES
LithostratigraphyTop depth [m]Lithostrat. unit135595845845236623662486254927542769276930413295329533563551356836333633392439914054417341734209
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]6.4230.68
Drill stem tests (DST)
Drill stem tests (DST)Test numberFrom depth MD
[m]To depth MD
Drill stem tests (DST)Test numberFinal shut-in pressure
[MPa]Final flow pressure
[MPa]Bottom hole pressure
Drill stem tests (DST)Test numberOil
[g/cm3]Gas grav. rel.airGOR
LogsLog typeLog top depth [m]Log bottom depth [m]CBL VDL GR CCL2721648CBL VDL GR CCL12003261CBL VDL GR CCL31673475CET GR12003261CET GR31673475CST27393285CST33074080CST40884307DIL LSS GR6184304DLL MSFL GR CAL32813677HDT32814305ISF LSS GR MSFL2213679LDL GR CAL CNL6184305NGT SDT32724305RFT32963626RFT33190RFT35954259RFT42070SHDT32813681VSP16244307
Casing and leak–off tests
Casing and leak–off testsCasing typeCasing diam.
[m]LOT/FIT mud eqv.
[g/cm3]Formation test typeCONDUCTOR30221.036222.00.00LOTSURF.COND.20619.026630.01.40LOTINTERM.13 3/81648.017 1/21667.01.66LOTINTERM.9 5/83275.012 1/43297.01.75LOTLINER73553.08 1/24303.00.00LOT
Drilling mudDepth MD [m]Mud weight [g/cm3]Visc. [mPa.s]Yield point [Pa]Mud typeDate measured341.2719.05.0WATER BASED22.01.19852220.00WATERBASED26.11.19846171.0944.07.0WATERBASED26.11.19846171.0944.07.0WATER BASED26.11.19846251.106.015.0WATERBASED26.11.19846251.106.015.0WATER BASED26.11.19846301.116.016.0WATER BASED27.11.19846301.106.016.0WATER BASED28.11.19846301.0713.04.0WATER BASED04.12.19846301.1514.04.0WATER BASED04.12.19846300.00WATERBASED29.11.19846301.116.016.0WATERBASED27.11.19846300.006.016.0WATERBASED28.11.19846300.0013.04.0WATERBASED04.12.19846300.0014.04.0WATERBASED04.12.19847001.1514.04.5WATERBASED04.12.19847001.1514.04.5WATER BASED04.12.19848851.1517.09.0WATER BASED05.12.19848851.1517.09.0WATERBASED05.12.198410761.1520.08.5WATERBASED06.12.198410761.1520.08.5WATER BASED06.12.198412271.1520.010.5WATER BASED07.12.198412271.1520.010.5WATERBASED07.12.198413541.1523.012.0WATERBASED11.12.198413541.1523.012.0WATER BASED11.12.198414441.1522.011.0WATER BASED11.12.198414441.1522.011.0WATERBASED11.12.198415811.1523.015.0WATERBASED11.12.198415811.1523.015.0WATER BASED11.12.198416671.1825.015.0WATER BASED11.12.198416671.2531.011.0OIL BASED13.12.198416671.2737.013.5OIL BASED16.12.198416671.0546.015.0OIL BASED16.12.198416671.5042.016.0OIL BASED16.12.198416671.2531.011.0OIL BASED13.12.198416670.0046.015.0OIL BASED15.12.198416671.1825.015.0WATERBASED11.12.198416671.2026.012.5OIL BASED11.12.198416670.0037.013.5OIL BASED15.12.198416670.0042.016.0OIL BASED15.12.198418371.5033.011.5OIL BASED19.12.198418371.5033.011.5OIL BASED18.12.198420671.5038.014.0OIL BASED20.12.198422111.5039.011.0OIL BASED20.12.198424021.5031.010.0OIL BASED26.12.198424601.5034.010.5OIL BASED26.12.198424771.5036.012.0OIL BASED26.12.198425761.5039.014.0OIL BASED26.12.198426931.5042.017.0OIL BASED26.12.198427381.5045.018.0OIL BASED26.12.198427801.5142.016.0OIL BASED27.12.198429211.5045.018.0OIL BASED01.01.198530871.5043.015.0OIL BASED01.01.198531171.3132.05.0OIL BASED24.03.198531511.5039.016.0OIL BASED01.01.198532531.5042.016.0OIL BASED01.01.198532971.2720.06.5WATER BASED06.01.198532971.5040.017.0OIL BASED02.01.198532971.5040.017.0OIL BASED03.01.198532971.5040.017.0OIL BASED06.01.198532971.2720.06.5WATER BASED06.01.198532971.5039.016.0OIL BASED01.01.198532971.5040.017.0OIL BASED02.01.198532971.5040.017.0OIL BASED03.01.198532971.5040.017.0OIL BASED06.01.198533011.2719.07.5WATER BASED06.01.198533241.2723.04.0OIL BASED21.03.198533401.2720.08.0WATER BASED07.01.198533481.2729.05.0OIL BASED24.03.198533481.2931.04.5OIL BASED24.03.198533481.2725.05.0OIL BASED18.03.198533481.2724.05.0OIL BASED19.03.198533481.2725.04.0OIL BASED20.03.198533481.2724.05.0OIL BASED19.03.198533481.2725.04.0OIL BASED20.03.198533481.2729.05.0OIL BASED24.03.198533481.2931.04.5OIL BASED24.03.198533501.2847.08.0OIL BASED17.03.198533501.2734.06.0OIL BASED17.03.198533501.2833.07.0OIL BASED17.03.198533501.2833.07.0OIL BASED17.03.198533501.2847.08.0OIL BASED17.03.198533681.2723.09.0WATER BASED07.01.198533871.2721.08.0WATER BASED07.01.198534321.2725.011.0WATER BASED10.01.198534451.2724.010.0WATER BASED14.01.198534571.2722.05.5WATER BASED21.01.198534571.2717.05.5WATER BASED14.01.198534571.2718.06.0WATER BASED15.01.198534571.2720.07.0WATER BASED16.01.198534571.2719.08.0WATER BASED18.01.198534571.2719.07.0WATER BASED21.01.198534571.2722.05.5WATER BASED21.01.198534571.2720.07.5WATER BASED14.01.198534571.2717.05.5WATER BASED14.01.198534571.2718.06.0WATER BASED15.01.198534571.2720.07.0WATER BASED16.01.198534571.2719.07.5WATER BASED17.01.198534571.2719.08.0WATER BASED18.01.198534571.2719.07.0WATER BASED21.01.198534571.2719.07.5WATER BASED17.01.198534671.2821.06.0WATER BASED21.01.198534721.2721.05.0WATER BASED21.01.198535001.2718.05.0WATER BASED23.01.198535451.3139.012.0OIL BASED25.02.198535451.2729.065.0OIL BASED25.02.198535451.2731.06.0OIL BASED26.02.198535451.2720.05.0OIL BASED27.02.198535451.2723.05.0OIL BASED01.03.198535451.2724.05.0OIL BASED03.03.198535451.2725.05.0OIL BASED03.03.198535451.2723.06.0OIL BASED04.03.198535451.2723.06.0OIL BASED05.03.198535451.2723.06.0OIL BASED06.03.198535451.2729.06.5OIL BASED08.03.198535451.2725.06.0OIL BASED10.03.198535451.2733.08.0OIL BASED10.03.198535451.2724.05.5OIL BASED10.03.198535451.2724.06.0OIL BASED12.03.198535451.2724.06.0OIL BASED13.03.198535451.2736.06.0OIL BASED14.03.198535451.2731.06.0OIL BASED26.02.198535451.2720.05.0OIL BASED27.02.198535451.2723.05.0OIL BASED01.03.198535451.2724.05.0OIL BASED03.03.198535451.2725.05.0OIL BASED03.03.198535451.2723.06.0OIL BASED04.03.198535451.2723.06.0OIL BASED05.03.198535451.2723.06.0OIL BASED06.03.198535451.2729.06.5OIL BASED08.03.198535451.2725.06.0OIL BASED10.03.198535451.2733.08.0OIL BASED10.03.198535451.2724.05.5OIL BASED10.03.198535451.2724.055.0OIL BASED11.03.198535451.2724.06.0OIL BASED12.03.198535451.2736.06.0OIL BASED14.03.198535451.2729.065.0OIL BASED25.02.198535451.2724.06.0OIL BASED13.03.198535451.2724.055.0OIL BASED11.03.198535581.2720.06.0WATER BASED24.01.198535801.2721.06.5WATER BASED29.01.198536801.2733.012.5OIL BASED04.02.198536801.2733.012.5OIL BASED04.02.198536801.2722.06.5WATER BASED04.02.198538711.2727.013.0OIL BASED04.02.198539721.2728.012.0OIL BASED05.02.198540461.2726.011.0OIL BASED06.02.198541201.2731.011.0OIL BASED07.02.198541201.2735.011.0OIL BASED08.02.198541201.2735.011.0OIL BASED08.02.198541661.2730.010.0OIL BASED10.02.198541891.2731.011.0OIL BASED10.02.198541891.2731.010.5OIL BASED10.02.198541891.2731.010.5OIL BASED10.02.198542281.2737.010.0OIL BASED12.02.198542681.2732.010.0OIL BASED12.02.198542771.2730.09.0OIL BASED13.02.198543031.2735.09.0OIL BASED18.02.198543031.2735.010.0OIL BASED17.02.198543031.2736.010.0OIL BASED17.02.198543031.2735.09.0OIL BASED17.02.198543031.2735.09.0OIL BASED18.02.198543031.2736.010.0OIL BASED19.02.198543031.2737.011.0OIL BASED21.02.198543031.2938.011.0OIL BASED21.02.198543031.2731.010.0OIL BASED14.02.198543031.2735.010.0OIL BASED17.02.198543031.2736.010.0OIL BASED17.02.198543031.2735.09.0OIL BASED17.02.198543031.2736.010.0OIL BASED19.02.198543031.2737.011.0OIL BASED21.02.198543031.2938.011.0OIL BASED21.02.1985
Pressure plotsThe 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 plotsDocument nameDocument formatDocument size [MB]0.23