Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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15.07.2024 - 01:28
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2/1-6

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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.
    2/1-6
    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).
    APPRAISAL
    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
    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.
    Discovery
    Name of the discovery the wellbore is related to.
    Well name
    Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    2/1-6
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    BP 80 - 27 B SP. 2268
    Production licence
    Official designation of the production licence the wellbore was drilled or planned to be drilled from ( well head posistion).
    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.
    BP Norway Limited U.A.
    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.
    413-L
    Drilling facility
    Norwegian Offshore Directorate's name of the facility which the wellbore was drilled from.
    Drilling days
    Number of days from wellbore entry to wellbore completion.
    105
    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,
    30.04.1984
    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.
    12.08.1984
    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.
    12.08.1986
    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.
    12.03.2011
    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.
    APPRAISAL
    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.
    DRY
    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.
    NO
    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.
    66.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4588.0
    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).
    4582.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    2.5
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    166
    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.
    56° 55' 14.81'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    3° 1' 38.37'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6308709.14
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    501663.54
    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.
    109
  • Wellbore history

    General
    Well 2/1-6 is located on the northern side of the Gyda structure on the Cod Terrace in the North Sea. The main target was the Late Jurassic Sandstone, informally called the Gyda sandstone member. The well was located such that it should prove the oil water contact of the 2/1-3 oil discovery, and by this establish whether 2/1-3, 2/1-4 and 1/3-3 all have encountered the same oil accumulation on the two sides of the saddle point. It should also test further the extent and the quality of this Upper Jurassic reservoir.
    Operations and results
    Appraisal well 2/1-6 was spudded with the semi-submersible installation Dyvi Alpha on 30 April 1984 and drilled to TD at 4583 m (4588 m loggers depth), one metre into Late Triassic sediments of the Skagerrak Formation. The well was drilled with seawater and pre-hydrated bentonite spud mud down to 635 m, with KCl/polymer mud from 635 m to 3424 m, with lignosulfonate mud from 3424 m to 4124 m, and with high temperature polymer mud from 4124 m to TD.
    The Gyda sandstone member was penetrated at 4173 m logger's depth. The reservoir is 205 metres thick, generally very fine to fine grained sandstone, but with a 28 metre thick siltstone incorporated in the uppermost part. Reservoir properties were very variable. Reasonable reservoir properties were found near the top of the reservoir. They were poor in an upper siltstone zone, in an intermediate 77 metre thick quartz overgrowth zone and at the base of the 2/1-3 sand where it shaled out into the Farsund Formation. Shows were recorded from 4174 to 4178 m in a sandstone that had very low permeability, and could not be tested. Minor patchily developed shows were observed from 4178 down to 4203 m, all within the fairly tight siltstone. No OWC was seen in the well. However, a possible OWC has been established at 4185 m (4160 m MSL), on the basis of a re-interpretation of RFT data from the wells 2/1-3, 4, 6 and 1/3-3 combined with pressure readings in the water zone of 2/1-6.
    Eight cores were cut between 4127 and 4165.35 m. Four cores were cut between 4303 and 4391.5 m. Recovery was 100% for all cores. For all cores the core depth is 4 m less than logger's depth. The RFT tool was run for pressure and fluid samples. A fluid sample was taken at 4208 m. Rig site resistivity measurements and laboratory water analysis confirmed the samples to be mud filtrate. Sampling was attempted in the interval 4173-4175 m. The sand interval was tight and neither pressure measurements nor sample were obtained.
    The well was permanently abandoned on 12 August 1984 as a dry appraisal well.
    Testing
    Two drill stem tests/water injection tests were performed in the Gyda member sandstone. Both tests confirmed the reservoir to be water bearing.
    DST1 perforated 4328.75 - 4340.75 m and produced 288 B/D of water with 1.17 specific gravity in the main flow period, through a 64/64" choke. In the following injection period the final injection rate was 240 B/D of treated sea water and the final surface injection pressure was 7000 psig.
    DST2 perforated 4210 - 4241 m and produced 3379 B/D of water with 1.17 specific gravity in the main flow through a 28/64" choke. In the following injection period the final injection rate, before acidization, was 2880 B/D of treated sea water and the final surface injection pressure was 5245psig. After acidization the final injection rate was 7544 B/D of treated sea water and the final surface injection pressure was 4955 psig.
    A number of temperature sensors were employed in the tests and maximum temperatures from 146 to 162 deg C were recorded. Among these maximum temperatures of 319 deg F (159.4 deg C) and 318 (158.9 deg C) in DST1 and DST2 respectively seem to be the more representative and in agreement with corrected wire line temperatures.
  • 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]
    170.00
    4581.00
  • 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
    4127.0
    4153.3
    [m ]
    2
    4153.7
    4181.3
    [m ]
    3
    4181.4
    4208.6
    [m ]
    4
    4208.5
    4235.4
    [m ]
    5
    4235.4
    4245.6
    [m ]
    6
    4245.6
    4254.7
    [m ]
    7
    4254.6
    4263.2
    [m ]
    8
    4263.3
    4265.4
    [m ]
    9
    4303.0
    4313.0
    [m ]
    10
    4313.0
    4336.8
    [m ]
    11
    4336.8
    4364.3
    [m ]
    12
    4364.3
    4391.5
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    226.4
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES
  • Core photos

    Core photos
    Core photo at depth: 4127-4133m
    Core photo at depth: 4133-4139m
    Core photo at depth: 4139-4144m
    Core photo at depth: 4145-4151m
    Core photo at depth: 4151-4154m
    4127-4133m
    4133-4139m
    4139-4144m
    4145-4151m
    4151-4154m
    Core photo at depth: 4153-4159m
    Core photo at depth: 4159-4165m
    Core photo at depth: 4165-4170m
    Core photo at depth: 4171-4177m
    Core photo at depth: 4177-4181m
    4153-4159m
    4159-4165m
    4165-4170m
    4171-4177m
    4177-4181m
    Core photo at depth: 4181-4187m
    Core photo at depth: 4187-4193m
    Core photo at depth: 4193-4199m
    Core photo at depth: 4199-4205m
    Core photo at depth: 4205-4209m
    4181-4187m
    4187-4193m
    4193-4199m
    4199-4205m
    4205-4209m
    Core photo at depth: 4208-4214m
    Core photo at depth: 4214-4220m
    Core photo at depth: 4220-4226m
    Core photo at depth: 4226-4232m
    Core photo at depth: 4232-4235m
    4208-4214m
    4214-4220m
    4220-4226m
    4226-4232m
    4232-4235m
    Core photo at depth: 4235-4241m
    Core photo at depth: 4241-4246m
    Core photo at depth: 4245-4251m
    Core photo at depth: 4251-4254m
    Core photo at depth: 4254-4260m
    4235-4241m
    4241-4246m
    4245-4251m
    4251-4254m
    4254-4260m
    Core photo at depth: 4260-4263m
    Core photo at depth: 4263-4266m
    Core photo at depth: 4303-4309m
    Core photo at depth: 4309-4314m
    Core photo at depth: 4313-4319m
    4260-4263m
    4263-4266m
    4303-4309m
    4309-4314m
    4313-4319m
    Core photo at depth: 4319-4325m
    Core photo at depth: 4325-4331m
    Core photo at depth: 4331-4336m
    Core photo at depth: 4336-4342m
    Core photo at depth: 4342-4347m
    4319-4325m
    4325-4331m
    4331-4336m
    4336-4342m
    4342-4347m
    Core photo at depth: 4348-4354m
    Core photo at depth: 4354-4360m
    Core photo at depth: 4360-4364m
    Core photo at depth: 4364-4370m
    Core photo at depth: 4370-4376m
    4348-4354m
    4354-4360m
    4360-4364m
    4364-4370m
    4370-4376m
    Core photo at depth: 4376-4382m
    Core photo at depth: 4382-4387m
    Core photo at depth: 4388-4392m
    Core photo at depth:  
    Core photo at depth:  
    4376-4382m
    4382-4387m
    4388-4392m
  • Palynological slides at the Norwegian Offshore Directorate

    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    4100.0
    [m]
    DC
    HRS
    4110.0
    [m]
    DC
    HRS
    4124.0
    [m]
    C
    APT
    4127.0
    [m]
    C
    HRS
    4132.0
    [m]
    C
    HRS
    4133.0
    [m]
    C
    APT
    4139.0
    [m]
    C
    APT
    4143.6
    [m]
    C
    HRS
    4145.0
    [m]
    C
    APT
    4148.0
    [m]
    C
    HRS
    4151.0
    [m]
    C
    APT
    4152.9
    [m]
    C
    HRS
    4153.0
    [m]
    C
    APT
    4156.5
    [m]
    C
    HRS
    4157.0
    [m]
    C
    APT
    4163.0
    [m]
    C
    APT
    4163.6
    [m]
    C
    HRS
    4168.7
    [m]
    C
    APT
    4168.9
    [m]
    C
    HRS
    4169.7
    [m]
    C
    APT
    4170.6
    [m]
    C
    APT
    4172.7
    [m]
    C
    APT
    4173.7
    [m]
    C
    APT
    4174.7
    [m]
    C
    APT
    4175.7
    [m]
    C
    APT
    4176.7
    [m]
    C
    APT
    4176.9
    [m]
    C
    HRS
    4177.7
    [m]
    C
    APT
    4178.7
    [m]
    C
    APT
    4181.0
    [m]
    C
    HRS
    4181.4
    [m]
    C
    APT
    4182.5
    [m]
    C
    APT
    4185.3
    [m]
    C
    HRS
    4185.4
    [m]
    C
    APT
    4186.4
    [m]
    C
    APT
    4189.4
    [m]
    C
    APT
    4191.5
    [m]
    C
    APT
    4194.4
    [m]
    C
    APT
    4196.4
    [m]
    C
    APT
    4197.3
    [m]
    C
    HRS
    4197.4
    [m]
    C
    APT
    4200.3
    [m]
    C
    APT
    4205.7
    [m]
    C
    HRS
    4208.2
    [m]
    C
    APT
    4210.1
    [m]
    C
    APT
    4211.4
    [m]
    C
    HRS
    4218.0
    [m]
    C
    HRS
    4220.1
    [m]
    C
    APT
    4222.5
    [m]
    C
    HRS
    4226.1
    [m]
    C
    APT
    4232.1
    [m]
    C
    APT
    4236.8
    [m]
    C
    HRS
    4237.0
    [m]
    C
    APT
    4239.3
    [m]
    C
    APT
    4244.0
    [m]
    C
    APT
    4246.0
    [m]
    C
    APT
    4246.0
    [m]
    C
    HRS
    4246.9
    [m]
    C
    APT
    4256.1
    [m]
    C
    APT
    4260.8
    [m]
    C
    APT
    4261.2
    [m]
    C
    APT
    4262.6
    [m]
    C
    HRS
    4304.5
    [m]
    C
    APT
    4305.1
    [m]
    C
    APT
    4307.5
    [m]
    C
    APT
    4309.0
    [m]
    C
    APT
    4321.5
    [m]
    C
    APT
    4329.2
    [m]
    C
    HRS
    4333.8
    [m]
    C
    HRS
    4334.2
    [m]
    C
    APT
    4336.5
    [m]
    C
    APT
    4350.1
    [m]
    C
    APT
    4350.5
    [m]
    C
    APT
    4351.8
    [m]
    C
    APT
    4355.8
    [m]
    C
    APT
    4360.8
    [m]
    C
    APT
    4362.1
    [m]
    C
    APT
    4362.5
    [m]
    C
    HRS
    4363.8
    [m]
    C
    APT
    4367.0
    [m]
    C
    APT
    4368.2
    [m]
    C
    APT
    4369.7
    [m]
    C
    APT
    4370.3
    [m]
    C
    APT
    4372.0
    [m]
    C
    HRS
    4372.3
    [m]
    C
    APT
    4375.2
    [m]
    C
    APT
    4377.2
    [m]
    C
    APT
    4379.2
    [m]
    C
    APT
    4381.3
    [m]
    C
    APT
    4383.2
    [m]
    C
    APT
    4385.2
    [m]
    C
    APT
    4387.2
    [m]
    C
    APT
    4389.2
    [m]
    C
    APT
    4391.0
    [m]
    C
    HRS
    4391.2
    [m]
    C
    APT
    4394.0
    [m]
    C
    HRS
    4400.0
    [m]
    C
    HRS
    4412.0
    [m]
    C
    HRS
    4445.0
    [m]
    C
    HRS
    4487.0
    [m]
    C
    HRS
    4526.0
    [m]
    C
    HRS
    4551.0
    [m]
    C
    HRS
    4566.0
    [m]
    C
    HRS
    4569.0
    [m]
    C
    HRS
  • Lithostratigraphy

  • Composite logs

    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.80
  • 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]
    pdf
    17.51
  • Drill stem tests (DST)

    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    4329
    4340
    25.4
    2.0
    4241
    4210
    11.1
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    16.000
    2.0
    12.500
    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
    2.0
  • Logs

    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL VDL GR
    500
    2000
    DIPMETER
    4114
    4563
    DLL MSFL GR SP CALI
    4113
    4583
    ISF BHC MAFL GR CALI SP
    2006
    3913
    ISF BHC MAFL GR CALI SP
    3600
    4123
    ISF GR SLS MSFL CALI SP
    626
    2001
    ISF LSS GR
    90
    635
    ISF LSS MSFL GR CALI SP
    4113
    4586
    LDL CNL NGL
    4113
    4587
    NGT RATIO
    4113
    4587
    VSP
    650
    4578
  • 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
    166.0
    36
    167.0
    0.00
    LOT
    SURF.COND.
    20
    626.0
    26
    635.0
    1.56
    LOT
    INTERM.
    13 3/8
    2006.0
    17 1/2
    2016.0
    1.90
    LOT
    INTERM.
    9 5/8
    4112.0
    12 1/4
    4121.0
    2.12
    LOT
    LINER
    7
    4579.0
    8 1/2
    4583.0
    0.00
    LOT
  • Drilling mud

    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    151
    1.05
    WATER BASED
    10.05.1984
    166
    1.04
    WATER BASED
    10.05.1984
    167
    1.05
    WATER BASED
    13.05.1984
    320
    1.08
    4.0
    5.0
    WATER BASED
    13.05.1984
    481
    1.09
    3.0
    8.0
    WATER BASED
    13.05.1984
    635
    1.15
    5.0
    26.0
    WATER BASED
    13.05.1984
    660
    1.14
    19.0
    28.0
    WATER BASED
    13.05.1984
    1140
    1.20
    14.0
    10.0
    WATER BASED
    14.05.1984
    1415
    1.42
    22.0
    12.0
    WATER BASED
    14.05.1984
    1718
    1.50
    22.0
    12.0
    WATER BASED
    14.05.1984
    1850
    1.50
    24.0
    6.2
    WATER BASED
    14.05.1984
    2010
    1.54
    23.0
    5.3
    WATER BASED
    15.05.1984
    2220
    1.55
    19.0
    6.2
    WATER BASED
    20.05.1984
    2414
    1.55
    17.0
    7.2
    WATER BASED
    20.05.1984
    2543
    1.55
    18.0
    5.8
    WATER BASED
    22.05.1984
    2743
    1.55
    21.0
    7.2
    WATER BASED
    23.05.1984
    2951
    1.56
    23.0
    5.8
    WATER BASED
    24.05.1984
    3013
    1.56
    22.0
    15.4
    WATER BASED
    25.05.1984
    3168
    1.57
    27.0
    13.4
    WATER BASED
    28.05.1984
    3208
    1.58
    21.0
    9.1
    WATER BASED
    28.05.1984
    3231
    1.58
    20.0
    11.0
    WATER BASED
    28.05.1984
    3300
    1.57
    19.0
    9.1
    WATER BASED
    29.05.1984
    3311
    1.58
    22.0
    5.8
    WATER BASED
    31.05.1984
    3354
    1.58
    23.0
    8.6
    WATER BASED
    01.06.1984
    3424
    1.58
    25.0
    8.2
    WATER BASED
    01.06.1984
    3486
    1.58
    30.0
    6.7
    WATER BASED
    04.06.1984
    3578
    1.58
    32.0
    8.2
    WATER BASED
    04.06.1984
    3625
    1.58
    32.0
    7.2
    WATER BASED
    04.06.1984
    3669
    1.58
    28.0
    6.7
    WATER BASED
    05.06.1984
    3716
    1.58
    30.0
    7.7
    WATER BASED
    06.06.1984
    3733
    1.58
    33.0
    7.7
    WATER BASED
    07.06.1984
    3746
    1.58
    33.0
    7.7
    WATER BASED
    08.06.1984
    3763
    1.58
    31.0
    7.2
    WATER BASED
    12.06.1984
    3768
    1.58
    30.0
    7.2
    WATER BASED
    12.06.1984
    3775
    1.58
    28.0
    6.2
    WATER BASED
    12.06.1984
    3811
    1.58
    34.0
    8.0
    WATER BASED
    15.06.1984
    3845
    1.58
    28.0
    6.0
    WATER BASED
    15.06.1984
    3876
    1.57
    29.0
    7.0
    WATER BASED
    15.06.1984
    3886
    1.59
    26.0
    6.2
    WATER BASED
    17.06.1984
    3927
    1.58
    30.0
    7.7
    WATER BASED
    17.06.1984
    3961
    1.58
    29.0
    9.6
    WATER BASED
    17.06.1984
    4011
    1.58
    28.0
    9.6
    WATER BASED
    20.06.1984
    4066
    1.58
    25.0
    13.4
    WATER BASED
    20.06.1984
    4118
    1.58
    21.0
    5.3
    WATER BASED
    21.06.1984
    4121
    1.58
    21.0
    5.3
    WATER BASED
    22.06.1984
    4121
    1.69
    26.0
    13.4
    WATER BASED
    27.06.1984
    4121
    1.58
    21.0
    5.3
    WATER BASED
    22.06.1984
    4121
    1.69
    26.0
    13.4
    WATER BASED
    27.06.1984
    4124
    1.56
    15.0
    9.6
    WATER BASED
    02.07.1984
    4137
    1.56
    19.0
    9.6
    WATER BASED
    02.07.1984
    4180
    1.56
    21.0
    11.0
    WATER BASED
    02.07.1984
    4235
    1.56
    23.0
    11.5
    WATER BASED
    03.07.1984
    4245
    1.56
    21.0
    11.0
    WATER BASED
    04.07.1984
    4262
    1.56
    18.0
    10.6
    WATER BASED
    05.07.1984
    4268
    1.56
    22.0
    10.6
    WATER BASED
    06.07.1984
    4284
    1.56
    19.0
    11.5
    WATER BASED
    06.07.1984
    4303
    1.56
    19.0
    12.0
    WATER BASED
    06.07.1984
    4313
    1.56
    20.0
    15.5
    WATER BASED
    10.07.1984
    4337
    1.56
    19.0
    15.4
    WATER BASED
    11.07.1984
    4378
    1.57
    20.0
    14.9
    WATER BASED
    12.07.1984
    4393
    1.56
    16.0
    6.2
    WATER BASED
    13.07.1984
    4478
    1.55
    21.0
    12.0
    WATER BASED
    16.07.1984
    4583
    1.55
    18.0
    12.0
    WATER BASED
    16.07.1984
  • Thin sections at the Norwegian Offshore Directorate

    Thin sections at the Norwegian Offshore Directorate
    Depth
    Unit
    4127.00
    [m ]
    4164.00
    [m ]
    4181.00
    [m ]
    4197.00
    [m ]
    4334.00
    [m ]
    4354.00
    [m ]
    4363.00
    [m ]
    4374.00
    [m ]
    4391.00
    [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 name
    Document format
    Document size [MB]
    PDF
    0.22