6/3-1

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• General information

  General information

  Attribute	Value
  Wellbore name Official name of wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.	6/3-1
  Type Wellbore type. Legal values: EXPLORATION, DEVELOPMENT, OTHER (see 'Purpose' for more information)	EXPLORATION
  Purpose Final 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
  Status Status 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 Norwegian Offshore Directorate. INJECTING: It was injected to the wellbore at the time of the operators last monthly report to the Norwegian Offshore Directorate. 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&A
  Factmaps in new window	link to map
  Main area Name of the area on the Norwegian Continental Shelf where the wellbore is located. Legal values: BARENTS SEA, NORWEGIAN SEA, NORTH SEA.	NORTH SEA
  Field Name of the field the wellbore is related to.	GAUPE
  Discovery Name of the discovery the wellbore is related to.	6/3-1 PI
  Well name Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.	6/3-1
  Seismic location Position of spud location on seismic survey lines. SP: shotpoint.	511-115 SP. 160
  Production licence Official designation of the production licence the wellbore was drilled or planned to be drilled from ( well head posistion).	086
  Drilling operator Name 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.	Den norske stats oljeselskap a.s
  Drill permit The drilling permit number together with the version of the drilling permit as stated in the drilling permit granted by the Norwegian Offshore Directorate.	441-L
  Drilling facility Norwegian Offshore Directorate's name of the facility which the wellbore was drilled from.	DEEPSEA BERGEN
  Drilling days Number of days from wellbore entry to wellbore completion.	92
  Entered date The date when he wellbore was spudded. For sidetracks: The date when new formation was drilled by kicking off from the mother-wellbore,	02.11.1984
  Completed date Exploration 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.	01.02.1985
  Release date Date 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.	01.02.1987
  Publication date Date 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.	11.02.2005
  Purpose - planned Pre-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
  Reentry Status 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
  Content For exploration wellbores, status of discovery. Legal values: 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. Legal values: WATER, CUTTINGS, NOT AVAILABLE, OIL, GAS/CONDENSATE, OIL/GAS, CO2, GAS, WATER/GAS, NOT APPLICABLE.	OIL/GAS
  Discovery wellbore Indicator 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, age Age of lithostratigraphic unit, 1st level, where hydrocarbons were encountered. Examples of legal values: CRETACEOUS, EARLY CRETACEOUS, LATE JURASSIC, EOCENE. See also Norwegian Offshore Directorate bulletins.	LATE JURASSIC
  1st level with HC, formation Name 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 Norwegian Offshore Directorate bulletins.	INTRA DRAUPNE FM SS
  2nd level with HC, age Age of lithostratigraphic unit, 2nd level, where hydrocarbons were encountered. Examples of legal values: CRETACEOUS, EARLY CRETACEOUS, LATE JURASSIC, EOCENE.	LATE CRETACEOUS
  2nd level with HC, formation Name of lithostartigraphic unit, 2nd 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.	HOD FM
  3rd level with HC, age Age of lithostratigraphic unit, 3rd level, where hydrocarbons were encountered. Examples of legal values: CRETACEOUS, EARLY CRETACEOUS, LATE JURASSIC, EOCENE.	LATE TRIASSIC
  3rd level with HC, formation Name of lithostartigraphic unit, 3rd 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.	SKAGERRAK FM
  Kelly bushing elevation [m] Elevation of the rotary kelly bushing (RKB) above mean sea level.	23.0
  Water depth [m] Depth in metres betweem mean sea level and sea floor.	86.0
  Total depth (MD) [m RKB] Total measured length of wellbore from kelly bushing to total depth (driller's depth).	3560.0
  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).	3560.0
  Maximum inclination [°] Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.	2
  Bottom hole temperature [°C] Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.	148
  Oldest penetrated age Age (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.	LATE TRIASSIC
  Oldest penetrated formation Name 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.	SKAGERRAK FM
  Geodetic datum Reference system for coordinates. Example of legal values: ED50.	ED50
  NS degrees Geographic coordinate of the wellhead, north-south degrees.	57° 58' 10.2'' N
  EW degrees Geographic coordinate of the wellhead, east-west degrees.	1° 55' 30.38'' E
  NS UTM [m] Universal Transverse Mercator coordinate of the wellhead, north-south.	6425966.20
  EW UTM [m] Universal Transverse Mercator coordinate of the wellhead, east-west.	436408.30
  UTM zone Universal Transverse Mercator zone. Examples of legal values: 31, 32, 33, 34.	31
  NPDID wellbore Norwegian Offshore Directorate's unique id for the wellbore.	450

• Wellbore history

  General

  Wildcat well 6/3-1 was drilled on the Pi-structure in the northwestern part of the block. The well is situated less than 1 km from the UK-Norwegian median line, where the UK Drake Field, an oil/gas field in UK block 2215was discovered close to the median line. Well 6/3-1 was designed to test possible hydrocarbon accumulations at different levels. The main target was Jurassic and Triassic sandstones. Secondary targets were Paleocene sandstones (Heimdal Formation), and Late Cretaceous porous/fractured chalk.

  Operations and results

  The well was spudded with the semi-submersible installation Deepsea Bergen 2 November 1984 and drilled to TD at 3560 m in the Triassic Skagerrak Formation. Drilling of the well proceeded without significant problems, but five and a half rig days were spent waiting on weather. The well was drilled with gel/seawater to 520 m, with gypsum/polymer from 520 m to 2926 m, and with lignite/lignosulphonate from 2926 m to TD.

  Target reservoir sandstones of Jurassic/Triassic age came in at 2965 m with oil and gas/condensate. A hydrocarbon column of 72 m was proven with oil/water contact at 3037 m. FMT gradients and oil stain on cores indicated a GOC at 3013 m. Secondary target sand (Heimdal Formation) was not found. Logs and shows indicated hydrocarbons in Late Cretaceous chalk/limestone, most strongly from 2900 m to 2925 m, but test of this interval was negative. FMT pressure measurements in the larger interval from 2804 m to 2918.5 m in the chalk were all unsuccessful and showed a tight formation. Eight cores were cut in the well from 2968 m to 3116.5 m. Segregated FMT samples were taken at 3021.5 m (0.87 g/cm3-oil and gas), at 3007.5 m (0.780 g/cm3-condensate, gas, and mud filtrate), at 3016 m (oil, mud filtrate, and gas), at 2992 m (0.77 g/cm3-condensate, mud filtrate, and gas), at 2998.5 m (condensate and gas), and at 2966 m (0.77 g/cm3-condensate, mud filtrate, and gas).

  The well was permanently abandoned as an oil and gas discovery on 2 January 1985.

  Testing

  Three Drill Stem Tests were performed. DST 1 at 3015 m to 3023 m produced 907.5 m3 oil/day and 140 700 Sm3 gas/day on a 64/64" choke and wellhead pressure equal to 51.7 bar. CO2 content in the gas was 2.2 % and H2S content was 1.1 ppm. DST 2 at 2978 m to 2993 m produced 409.4 m3 oil/day and 889 900 Sm3 gas/day on a 72/64" choke and wellhead pressure equal to 95.8 bar. CO2 content in the gas was 2.0 % and H2S content was 2.0 ppm. DST 3 at 2902-2921 m was opened up on a 12/64" choke. It gave no response from the well. Acid was pumped to stimulate flow, but only 2.6 m3 diesel cushion was produced before the well died. Mud with traces of oil was recovered when reversing out the string volume above the circulating valve.

• Cuttings at the Norwegian Offshore Directorate

  Cuttings at the Norwegian Offshore Directorate

  Cuttings available for sampling?	YES

  Cuttings at the Norwegian Offshore Directorate

  Cutting sample, top depth [m]	Cutting samples, bottom depth [m]
  180.00	3560.00

• Cores at the Norwegian Offshore Directorate

  Cores at the Norwegian Offshore Directorate

  Core sample number	Core sample - top depth	Core sample - bottom depth	Core sample depth - uom
  1	2967.0	2985.3	[m ]
  2	2986.0	2987.7	[m ]
  3	2988.0	3006.7	[m ]
  4	3007.0	3024.9	[m ]
  5	3025.0	3043.0	[m ]
  6	3043.0	3061.6	[m ]
  7	3061.6	3089.0	[m ]
  8	3089.0	3116.5	[m ]

  Cores at the Norwegian Offshore Directorate

  Total core sample length [m]	148.1

  Cores at the Norwegian Offshore Directorate

  Cores available for sampling?	YES

• Core photos

  Core photos

  2967-2985m	2967-2985m	2967-2985m	2967-2985m	2967-2985m
  2967-2985m	2967-2985m	2967-2985m	2967-2985m	2967-2985m
  2967-2985m	2967-2985m	2967-2985m	2967-2985m	3025-3043m
  2967-2985m	2967-2985m	2967-2985m	2967-2985m	2967-2985m
  2967-2985m	2967-2985m	2967-2985m	2967-2985m	2967-2985m
  2967-2985m	2967-2985m	2967-2985m	2967-2985m	2967-2985m
  2967-2985m	2967-2985m	2986-2987m	2986-2987m	2986-2987m
  2988-3006m	2988-3006m	2988-3006m	2988-3006m	2988-3006m
  2988-3006m	2988-3006m	2988-3006m	2988-3006m	2988-3006m
  2988-3006m	2988-3006m	2988-3006m	2988-3006m	2988-3006m
  2988-3006m	2988-3006m	2988-3006m	2988-3006m	2988-3006m
  2988-3006m	2988-3006m	2988-3006m	2988-3006m	2988-3006m
  2988-3006m	2988-3006m	2988-3006m	2988-3006m	2988-3006m
  2988-3006m	2988-3006m	3007-3025m	3007-3025m	3007-3025m
  3007-3025m	3007-3025m	3007-3025m	3007-3025m	3007-3025m
  3007-3025m	3007-3025m	3007-3024m	3007-3025m	3007-3025m
  3007-3025m	3007-3025m	3007-3025m	3007-3025m	3007-3025m
  3007-3025m	3007-3025m	3007-3025m	3007-3025m	3007-3025m
  3007-3025m	3007-3025m	3007-3025m	3007-3025m	3007-3025m
  3007-3025m	3025-3043m	3025-3043m	3025-3043m	3025-3043m
  3025-3043m	3025-3043m	3025-3043m	3025-3043m	3025-3043m
  3025-3043m	3025-3043m	3025-3043m	3025-3043m	3025-3043m
  3025-3043m	3025-3043m	3025-3043m	3025-3043m	3025-3043m
  3025-3043m	3025-3043m	3025-3043m	3025-3043m	3025-3043m
  3025-3043m	3025-3043m	3025-3043m	3025-3043m	3025-3043m
  3043-3061m	3043-3061m	3043-3061m	3043-3061m	3043-3061m
  3043-3061m	3043-3061m	3043-3061m	3043-3061m	3043-3061m
  3043-3061m	3043-3061m	3043-3061m	3043-3061m	3043-3061m
  3043-3061m	3043-3061m	3043-3061m	3043-3061m	3043-3061m
  3043-3061m	3043-3061m	3043-3061m	3043-3061m	3043-3061m
  3043-3061m	3043-3061m	3043-3061m	3043-3061m	3043-3061m
  3043-3061m	3061-3089m	3061-3089m	3061-3089m	3061-3089m
  3061-3089m	3061-3089m	3061-3089m	3061-3089m	3061-3089m
  3061-3089m	3061-3089m	3061-3089m	3061-3089m	3061-3089m
  3061-3089m	3061-3089m	3061-3089m	3061-3089m	3061-3089m
  3061-3089m	3061-3089m	3061-3089m	3061-3089m	3061-3089m
  3061-3089m	3061-3089m	3061-3089m	3061-3089m	3061-3089m
  3061-3089m	3061-3089m	3061-3089m	3061-3089m	3061-3089m
  3061-3089m	3061-3089m	3061-3089m	3061-3089m	3061-3089m
  3061-3089m	3061-3089m	3061-3089m	3061-3089m	3061-3089m
  3061-3089m	3061-3089m	3089-3116m	3089-3116m	3089-3116m
  3089-3116m	3089-3116m	3089-3116m	3089-3116m	3089-3116m
  3089-3116m	3089-3116m	3089-3116m	3089-3116m	3089-3116m
  3089-3116m	3089-3116m	3089-3116m	3089-3116m	3089-3116m
  3089-3116m	3089-3116m	3089-3116m	3089-3116m	3089-3116m
  3089-3116m	3089-3116m	3089-3116m	3089-3116m	3089-3116m
  3089-3116m	3089-3116m	3089-3116m	3089-3116m	3089-3116m
  3089-3116m	3089-3116m	3089-3116m	3089-3116m	3089-3116m
  3089-3116m	3089-3116m	3089-3116m	3089-3116m	3089-3116m
  3089-3116m	3089-3116m	3089-3116m

• Palynological slides at the Norwegian Offshore Directorate

  Palynological slides at the Norwegian Offshore Directorate

  Sample depth	Depth unit	Sample type	Laboratory
  2410.0	[m]	DC
  2445.0	[m]	DC
  2475.0	[m]	DC
  2507.5	[m]	SWC
  2537.5	[m]	SWC
  2567.5	[m]	SWC
  2602.5	[m]	SWC
  2640.0	[m]	DC
  2960.0	[m]	DC	STATOIL
  2965.0	[m]	DC	STATOI
  2969.5	[m]	C
  2970.0	[m]	DC	STATOIL
  2975.0	[m]	DC	STATOI
  2980.0	[m]	DC	STATOI
  2980.7	[m]	C
  2985.0	[m]	DC	STATOIL
  2986.8	[m]	C
  2987.5	[m]	C
  2988.3	[m]	C
  2990.0	[m]	DC	STATOIL
  2995.0	[m]	DC	STATOI
  2996.4	[m]	C
  3000.0	[m]	DC	STATOIL
  3004.4	[m]	C
  3007.0	[m]	DC	STATOIL
  3011.5	[m]	SWC
  3012.5	[m]	SWC	STATOIL
  3020.0	[m]	DC	STATOI
  3022.7	[m]	C
  3027.5	[m]	SWC	STATOIL
  3028.5	[m]	SWC
  3032.5	[m]	SWC	STATOIL
  3037.0	[m]	DC	STATOI
  3043.5	[m]	SWC
  3045.0	[m]	DC	STATOIL
  3057.5	[m]	SWC	STATOI
  3065.0	[m]	DC	STATOI
  3400.0	[m]	DC	STATOI
  3410.0	[m]	DC	STATOI
  3420.0	[m]	DC	STATOI
  3430.0	[m]	DC	STATOI
  3450.0	[m]	DC	STATOI
  3460.0	[m]	DC	STATOI
  3470.0	[m]	DC	STATOI
  3480.0	[m]	DC	STATOI
  3490.0	[m]	DC	STATOI
  3500.0	[m]	DC	STATOI
  3510.0	[m]	DC	STATOI
  3520.0	[m]	DC	STATOI
  3530.0	[m]	DC	STATOI
  3540.0	[m]	DC	STATOI
  3550.0	[m]	DC	STATOI
  3560.0	[m]	DC	STATOI

• Oil samples at the Norwegian Offshore Directorate

  Oil samples at the Norwegian Offshore Directorate

  Test type	Bottle number	Top depth MD [m]	Bottom depth MD [m]	Fluid type	Test time	Samples available
  DST	TEST1	3023.00	3015.00		08.01.1985 - 00:00	YES
  DST	TEST2	2993.00	2978.00		15.01.1985 - 22:30	YES
  DST	TEST3	2921.00	2902.00		21.01.1985 - 00:00	YES

• Lithostratigraphy

  Lithostratigraphy

  Top depth [mMD RKB]	Lithostrat. unit
  109	NORDLAND GP
  1183	HORDALAND GP
  2435	ROGALAND GP
  2435	BALDER FM
  2449	SELE FM
  2536	LISTA FM
  2637	VÅLE FM
  2673	SHETLAND GP
  2673	EKOFISK FM
  2679	TOR FM
  2744	HOD FM
  2922	CROMER KNOLL GP
  2922	SOLA FM
  2950	ÅSGARD FM
  2963	VIKING GP
  2963	DRAUPNE FM
  2965	INTRA DRAUPNE FM SS
  2978	NO GROUP DEFINED
  2978	SKAGERRAK FM

• Composite logs

  Composite logs

  Document name	Document format	Document size [MB]
  450	pdf	0.54

• Geochemical information

  Geochemical information

  Document name	Document format	Document size [MB]
  450_1	pdf	6.74

• Documents – older Norwegian Offshore Directorate WDSS reports and other related documents

  Documents – older Norwegian Offshore Directorate WDSS reports and other related documents

  Document name	Document format	Document size [MB]
  450_01_WDSS_General_Information	pdf	0.26
  450_02_WDSS_completion_log	pdf	0.26

• 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 name	Document format	Document size [MB]
  450_01_Completion_Report	pdf	13.18
  450_02_Completion_log	pdf	1.98

• Drill stem tests (DST)

  Drill stem tests (DST)

  Test number	From depth MD [m]	To depth MD [m]	Choke size [mm]
  1.0	3015	3023	19.5
  1.1	3015	3023	25.4
  2.0	2978	2993	25.4
  3.0	2902	2921	0.0

  Drill stem tests (DST)

  Test number	Final shut-in pressure [MPa]	Final flow pressure [MPa]	Bottom hole pressure [MPa]	Downhole temperature [°C]
  1.0
  1.1
  2.0	36.000	12.000	35.000
  3.0			39.000

  Drill stem tests (DST)

  Test number	Oil [Sm3/day]	Gas [Sm3/day]	Oil density [g/cm3]	Gas grav. rel.air	GOR [m3/m3]
  1.0	765	121000	0.860		158
  1.1	907	141000	0.860		155
  2.0	409	889900	0.768		2176
  3.0

• Logs

  Logs

  Log type	Log top depth [m]	Log bottom depth [m]
  ACBL VDL GR	110	1600
  ACBL VDL GR	1001	2885
  ACBL VDL GR	2700	3052
  CDL CNL GR CAL	1599	2925
  CDL CNL GR CAL	2884	3558
  CDL CNL GR CAL SP	2885	3114
  CDL GR CAL	501	1627
  DIFL BHC AC GR SP CAL	110	3559
  DIPLOG	2440	3559
  DLL ML	2600	3115
  DLWD	1632	3560
  FMT	2804	2902
  FMT	2966	3106
  VELOCITY	830	3560

• Casing and leak–off tests

  Casing and leak–off tests

  Casing type	Casing diam. [inch]	Casing depth [m]	Hole diam. [inch]	Hole depth [m]	LOT/FIT mud eqv. [g/cm3]	Formation test type
  CONDUCTOR	30	170.0	36	175.0	0.00	LOT
  SURF.COND.	20	502.0	26	520.0	1.37	LOT
  INTERM.	13 3/8	1600.0	17 1/2	1630.0	1.79	LOT
  INTERM.	9 5/8	2889.0	12 1/4	2926.0	1.70	LOT
  LINER	7	3560.0	8 1/2	3560.0	0.00	LOT

• Drilling mud

  Drilling mud

  Depth MD [m]	Mud weight [g/cm3]	Visc. [mPa.s]	Yield point [Pa]	Mud type	Date measured
  137	1.04	130.0	24.0	WATER BASED	05.11.1984
  172	1.04	44.0	16.0	WATER BASED	05.11.1984
  175	1.06	48.0	16.0	WATER BASED	05.11.1984
  520	1.09	42.0	13.0	WATER BASED	06.11.1984
  520	1.10	41.0	13.0	WATER BASED	07.11.1984
  520	1.10	41.0	13.0	WATER BASED	07.11.1984
  686	1.12	49.0	11.5	WATER BASED	12.11.1984
  928	1.14	51.0	11.5	WATER BASED	12.11.1984
  1050	1.14	51.0	11.5	WATER BASED	12.11.1984
  1225	1.15	51.0	11.5	WATER BASED	12.11.1984
  1456	1.14	61.0	12.4	WATER BASED	13.11.1984
  1630	1.15	62.0	12.4	WATER BASED	14.11.1984
  1630	1.21	57.0	9.0	WATER BASED	19.11.1984
  1630	1.21	57.0	9.0	WATER BASED	19.11.1984
  1700	1.20	61.0	7.0	WATER BASED	22.11.1984
  1848	1.20	64.0	9.0	WATER BASED	22.11.1984
  2156	1.18	46.0	7.0	WATER BASED	23.11.1984
  2555	1.20	48.0	9.0	WATER BASED	26.11.1984
  2630	1.21	52.0	11.0	WATER BASED	26.11.1984
  2656	1.21	47.0	11.0	WATER BASED	27.11.1984
  2757	1.20	46.0	9.6	WATER BASED	29.11.1984
  2870	1.20	44.0	9.0	WATER BASED	30.11.1984
  2926	1.35	45.0	7.7	WATER BASED	03.12.1984
  2968	1.45			WATER BASED	11.12.1984
  3021	1.45	54.0	6.0	WATER BASED	25.01.1985
  3066	1.35	60.0	6.0	WATER BASED	02.01.1985
  3117	1.40	57.0	6.0	WATER BASED	17.12.1984
  3454	1.40	54.0	7.2	WATER BASED	27.12.1984
  3560	1.38	53.0	6.2	WATER BASED	27.12.1984

• 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 name	Document format	Document size [MB]
  450_Formation_pressure_(Formasjonstrykk)	pdf	0.22