Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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22.12.2024 - 01:25
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34/10-23

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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.
    34/10-23
    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
    Multilateral
    Indicator telling if the parent well is multilateral, meaning it has more than one branch radiating from the main borehole. Example of legal values: YES, NO. See also Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    NO
    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.
    34/10-23
    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.
    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.
    465-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.
    161
    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,
    06.05.1985
    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.
    13.10.1985
    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.
    13.10.1987
    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.
    10.01.2012
    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
    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.
    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.
    MIDDLE 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.
    TARBERT FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    29.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    135.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4764.0
    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).
    4764.0
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    162
    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.
    STATFJORD GP
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    61° 1' 6.35'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 19' 1.57'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6765193.09
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    463084.94
    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.
    476

  • Wellbore history
    General
    Well 34/10-23 was drilled on the Gullfaks Gamma structure, south-southeast of the Gullfaks Sør Field in the Northern North Sea. The objectives were to prove a significant hydrocarbon accumulation, with the Brent Group as the primary target and the Early Jurassic as secondary target. The first well on the structure, well 34/10-20, had the same targets as 34/10-23, but was terminated in the Early Cretaceous due to technical problems.
    Operations and results
    Wildcat well 34/10-23 was spudded with the semi-submersible installation Dyvi Delta on 6 May 1985 and drilled to TD at 4764 m into Sinemurian /possibly Rhaetian age sediments of the Statfjord Formation. The well took 28 days more than prognosed to drill. The main part of the extra time came in the 8 1/2" section, where among many other things, the BOP stack was pulled for inspection and repairs. A flow occurred at 4080 m just above top Brent Group, and approximately three days were used to bring the well under control. At 4409 m (4406.5 m TVD RKB) the deviation exceeded 5 deg. The last survey, at 4514 m (4510.8 m TVD RKB) m showed 9.1 deg deviation. If this deviation is extrapolated the vertical depth at TD is 4756.2, ca 8 m short of measured depth. The well was drilled with seawater and hi-vis pills down to 1252 m, with gypsum/lignosulphonate mud from 1252 to 3118 m, and with gypsum/lignosulphonate/lignite mud from 3118 m to 4525 m. At 4509 m the pipe stuck, and imco-spot/pipelax pills with 3% diesel were placed to free it. The final section from 4525 m to TD was drilled with a gel/lignosulphonate/lignite/Anco Resin mud system.
    The pore pressure increased through the entire Cretaceous section and reached a maximum of 1.96 g/cc at the top of the Brent Group. Gas bearing Brent sandstone was encountered at 4083 m, approximately 100 m deeper than prognosed. A gas-water contact established at 4120 m. Analyses of the gas and the DST liquids showed a condensate character with significant contents of heavier components up to C35, including biomarkers.
    Oil shows were recorded in sandstones in the Lista Formation from 2020 to 2050 m, and in the Kyrre Formation around 2954 m. Weak shows on limestone was recorded in the Svarte Formation from 3640 to 3714 m. Intermittent fluorescence was recorded on sandstones on cores, sidewall cores and cuttings below the hydrocarbon-bearing reservoir down to TD. Some of these could be due to pipe-freeing agents added at 4509 m.
    Eleven cores were cut from 4082 m to 4308 m in the Tarbert, Ness, Etive, and Rannoch formations with an average recovery close to 100%. RFT wire line fluid samples were taken at 4084 m, 4176 m, 4718.5 m, and 4718.6 m.
    The well was permanently abandoned on 13 October 1985 as a gas/condensate discovery.
    Testing
    One drill stem test, DST1, was performed in the interval 4085 - 4095 m. The test produced 1720000 Sm3 gas, 150 Sm3 oil, and 15 m3 water per day through a 22.2 mm choke. The initial reservoir pressure was 785.3 bar and the draw-down was 41 bar. The GOR was 11500 Sm3/Sm3. The DST temperature was 150 deg C.

  • 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]
    230.00
    4764.00

  • 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
    4082.0
    4100.6
    [m ]
    2
    4103.0
    4130.5
    [m ]
    3
    4130.5
    4144.0
    [m ]
    4
    4144.2
    4167.0
    [m ]
    5
    4167.5
    4169.0
    [m ]
    6
    4169.7
    4197.0
    [m ]
    7
    4197.6
    4210.0
    [m ]
    8
    4211.6
    4224.0
    [m ]
    9
    4225.1
    4253.0
    [m ]
    10
    4253.0
    4279.4
    [m ]
    11
    4280.0
    4308.0
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    218.3
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 4082-4088m
    Core photo at depth: 4088-4094m
    Core photo at depth: 4094-4100m
    Core photo at depth: 4100-4100m
    Core photo at depth: 4103-4109m
    4082-4088m
    4088-4094m
    4094-4100m
    4100-4100m
    4103-4109m
    Core photo at depth: 4109-4115m
    Core photo at depth: 4115-4121m
    Core photo at depth: 4121-4127m
    Core photo at depth: 4127-4130m
    Core photo at depth: 4130-4136m
    4109-4115m
    4115-4121m
    4121-4127m
    4127-4130m
    4130-4136m
    Core photo at depth: 4136-4142m
    Core photo at depth: 4142-4144m
    Core photo at depth: 4144-4150m
    Core photo at depth: 4150-4156m
    Core photo at depth: 4156-4162m
    4136-4142m
    4142-4144m
    4144-4150m
    4150-4156m
    4156-4162m
    Core photo at depth: 4162-4167m
    Core photo at depth: 4167-4169m
    Core photo at depth: 4169-4175m
    Core photo at depth: 4175-4181m
    Core photo at depth: 4181-4187m
    4162-4167m
    4167-4169m
    4169-4175m
    4175-4181m
    4181-4187m
    Core photo at depth: 4187-4193m
    Core photo at depth: 4193-4197m
    Core photo at depth: 4197-4203m
    Core photo at depth: 4203-4209m
    Core photo at depth: 4209-4210m
    4187-4193m
    4193-4197m
    4197-4203m
    4203-4209m
    4209-4210m
    Core photo at depth: 4211-4217m
    Core photo at depth: 4217-4223m
    Core photo at depth: 4223-4224m
    Core photo at depth: 4225-4231m
    Core photo at depth: 4231-4237m
    4211-4217m
    4217-4223m
    4223-4224m
    4225-4231m
    4231-4237m
    Core photo at depth: 4237-4243m
    Core photo at depth: 4243-4249m
    Core photo at depth: 4249-4253m
    Core photo at depth: 4253-4259m
    Core photo at depth: 4259-4265m
    4237-4243m
    4243-4249m
    4249-4253m
    4253-4259m
    4259-4265m
    Core photo at depth: 4265-4271m
    Core photo at depth: 4271-4277m
    Core photo at depth: 4277-4279m
    Core photo at depth: 4280-4288m
    Core photo at depth: 4286-4292m
    4265-4271m
    4271-4277m
    4277-4279m
    4280-4288m
    4286-4292m
    Core photo at depth: 4292-4298m
    Core photo at depth: 4298-4304m
    Core photo at depth: 4304-4308m
    Core photo at depth:  
    Core photo at depth:  
    4292-4298m
    4298-4304m
    4304-4308m

  • 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
    4085.00
    4095.00
    CONDENSATE
    28.09.1985 - 16:35
    YES

  • 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
    224.0
    36
    225.0
    0.00
    LOT
    CONDUCTOR
    30
    225.0
    36
    227.0
    0.00
    LOT
    SURF.COND.
    20
    1239.0
    26
    1252.0
    1.69
    LOT
    INTERM.
    13 3/8
    3100.0
    17 1/2
    3118.0
    1.91
    LOT
    INTERM.
    13 3/8
    3104.0
    17 1/2
    3115.0
    1.91
    LOT
    INTERM.
    9 5/8
    3834.0
    12 1/4
    3850.0
    2.13
    LOT
    LINER
    7
    4525.0
    8 1/2
    4525.0
    2.20
    LOT
    OPEN HOLE
    4764.0
    5 7/8
    4764.0
    0.00
    LOT

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    4085
    4095
    22.2
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    28.000
    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
    150
    1700000
    0.820
    0.650
    11400

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL VDL CCL
    900
    3100
    CBL VDL CCL
    2200
    3830
    CBL VDL CCL
    3300
    4538
    CST GR
    4720
    4749
    DLL MSFL GR
    4050
    4761
    ISF LSS MSFL GR
    224
    4764
    LDL CNL GR
    1239
    4765
    RFT GR
    4084
    4140
    RFT GR
    4084
    4096
    RFT GR
    4084
    4141
    RFT GR
    4176
    4281
    RFT GR
    4435
    4439
    RFT GR
    4715
    4719
    RFT GR
    4716
    4750
    SHDT GR
    3836
    4485
    VSP
    224
    4764

  • Lithostratigraphy

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.42
    pdf
    0.41
    pdf
    6.65

  • 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
    3.06
    pdf
    41.13
    pdf
    38.88

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    1161
    1.65
    29.0
    3.9
    WATER BASED
    09.10.1985
    2014
    1.20
    20.0
    3.9
    WATER BASED
    21.05.1985
    2054
    1.25
    17.0
    3.9
    WATER BASED
    21.05.1985
    2056
    1.33
    22.0
    4.9
    WATER BASED
    21.05.1985
    2283
    1.34
    24.0
    5.4
    WATER BASED
    22.05.1985
    2389
    1.38
    22.0
    6.9
    WATER BASED
    23.05.1985
    2743
    1.45
    55.0
    9.0
    WATER BASED
    29.05.1985
    2955
    1.45
    9.0
    13.8
    WATER BASED
    29.05.1985
    3115
    1.45
    14.0
    8.9
    WATER BASED
    05.06.1985
    3120
    1.37
    10.0
    6.0
    WATER BASED
    10.06.1985
    3503
    1.73
    25.0
    10.0
    WATER BASED
    17.06.1985
    3503
    1.64
    25.0
    7.0
    WATER BASED
    14.06.1985
    3503
    1.73
    25.0
    10.0
    WATER BASED
    17.06.1985
    3549
    1.77
    26.0
    9.0
    WATER BASED
    17.06.1985
    3789
    1.81
    56.0
    11.0
    WATER BASED
    25.06.1985
    3924
    1.86
    25.0
    9.9
    WATER BASED
    16.07.1985
    3963
    1.92
    28.0
    4.9
    WATER BASED
    16.07.1985
    4007
    1.97
    35.0
    5.8
    WATER BASED
    16.07.1985
    4080
    2.05
    41.0
    6.9
    WATER BASED
    17.07.1985
    4080
    2.07
    47.5
    7.4
    WATER BASED
    18.07.1985
    4080
    2.07
    47.5
    7.4
    WATER BASED
    18.07.1985
    4082
    2.09
    42.0
    6.4
    WATER BASED
    19.07.1985
    4100
    2.06
    29.0
    3.9
    WATER BASED
    29.07.1985
    4100
    2.03
    28.0
    3.4
    WATER BASED
    29.07.1985
    4100
    2.03
    28.0
    3.4
    WATER BASED
    29.07.1985
    4120
    2.06
    29.0
    3.9
    WATER BASED
    25.09.1985
    4308
    2.01
    33.0
    5.4
    WATER BASED
    07.08.1985
    4438
    2.01
    32.0
    7.0
    WATER BASED
    16.09.1985
    4490
    2.04
    33.0
    5.9
    WATER BASED
    15.08.1985
    4525
    2.01
    31.0
    4.5
    WATER BASED
    19.08.1985
    4569
    1.98
    30.0
    4.9
    WATER BASED
    02.09.1985
    4576
    1.96
    32.0
    3.9
    WATER BASED
    02.09.1985

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    3887.5
    [m]
    DC
    GEOCHEM
    3897.5
    [m]
    DC
    GEOCHE
    3905.0
    [m]
    DC
    GEOCHE
    3917.5
    [m]
    DC
    GEOCHE
    3925.0
    [m]
    DC
    GEOCHE
    3932.5
    [m]
    DC
    GEOCHE
    3945.0
    [m]
    DC
    GEOCHE
    3957.5
    [m]
    DC
    GEOCHE
    3962.5
    [m]
    DC
    GEOCHE
    3967.5
    [m]
    DC
    GEOCHE
    3977.5
    [m]
    DC
    GEOCHE
    3985.0
    [m]
    DC
    GEOCHE
    4005.0
    [m]
    DC
    GEOCHE
    4015.0
    [m]
    DC
    GEOCHE
    4022.5
    [m]
    DC
    GEOCHE
    4035.0
    [m]
    DC
    GEOCHE
    4057.5
    [m]
    DC
    GEOCHE
    4082.5
    [m]
    DC
    GEOCHE
    4082.7
    [m]
    C
    OD
    4083.0
    [m]
    C
    RRI
    4087.2
    [m]
    C
    OD
    4090.0
    [m]
    DC
    GEOCHEM
    4092.8
    [m]
    C
    OD
    4097.9
    [m]
    C
    OD
    4098.0
    [m]
    C
    RRI
    4105.7
    [m]
    C
    OD
    4107.5
    [m]
    C
    OD
    4109.7
    [m]
    C
    OD
    4114.8
    [m]
    C
    OD
    4116.3
    [m]
    C
    OD
    4120.7
    [m]
    C
    OD
    4124.1
    [m]
    C
    OD
    4126.7
    [m]
    C
    OD
    4130.1
    [m]
    C
    OD
    4134.6
    [m]
    C
    OD
    4134.6
    [m]
    C
    OD
    4139.5
    [m]
    C
    OD
    4141.4
    [m]
    C
    OD
    4143.0
    [m]
    C
    MOBIL
    4144.8
    [m]
    C
    OD
    4147.2
    [m]
    C
    OD
    4152.0
    [m]
    C
    OD
    4153.7
    [m]
    C
    OD
    4158.7
    [m]
    C
    OD
    4161.7
    [m]
    C
    OD
    4162.7
    [m]
    C
    OD
    4166.6
    [m]
    C
    OD
    4167.9
    [m]
    C
    OD
    4167.9
    [m]
    C
    OD
    4172.7
    [m]
    C
    OD
    4174.7
    [m]
    C
    OD
    4177.0
    [m]
    C
    OD
    4180.8
    [m]
    C
    OD
    4180.8
    [m]
    C
    RRI
    4181.3
    [m]
    C
    OD
    4182.4
    [m]
    C
    OD
    4183.6
    [m]
    C
    RRI
    4186.5
    [m]
    C
    OD
    4187.6
    [m]
    C
    RRI
    4189.4
    [m]
    C
    OD
    4191.2
    [m]
    C
    RRI
    4191.7
    [m]
    C
    OD
    4192.9
    [m]
    C
    OD
    4193.8
    [m]
    C
    OD
    4196.2
    [m]
    C
    OD
    4196.8
    [m]
    C
    RRI
    4198.2
    [m]
    C
    OD
    4200.5
    [m]
    C
    OD
    4201.8
    [m]
    C
    OD
    4205.5
    [m]
    C
    OD
    4207.5
    [m]
    C
    OD
    4209.0
    [m]
    C
    OD
    4209.5
    [m]
    C
    OD
    4210.0
    [m]
    C
    RRI
    4212.1
    [m]
    C
    OD
    4214.2
    [m]
    C
    OD
    4214.3
    [m]
    C
    RRI
    4216.1
    [m]
    C
    OD
    4217.9
    [m]
    C
    OD
    4218.5
    [m]
    C
    RRI
    4221.6
    [m]
    C
    RRI
    4221.9
    [m]
    C
    OD
    4223.2
    [m]
    C
    OD
    4225.8
    [m]
    C
    OD
    4226.3
    [m]
    C
    RRI
    4227.9
    [m]
    C
    OD
    4228.0
    [m]
    C
    RRI
    4228.6
    [m]
    C
    OD
    4230.0
    [m]
    C
    RRI
    4230.8
    [m]
    C
    OD
    4233.7
    [m]
    C
    OD
    4234.6
    [m]
    C
    OD
    4234.7
    [m]
    C
    RRI
    4234.8
    [m]
    C
    RRI
    4235.8
    [m]
    C
    OD
    4236.8
    [m]
    C
    OD
    4237.3
    [m]
    C
    OD
    4237.8
    [m]
    C
    RRI
    4241.0
    [m]
    C
    OD
    4242.1
    [m]
    C
    RRI
    4242.1
    [m]
    C
    OD
    4245.3
    [m]
    C
    OD
    4248.7
    [m]
    C
    OD
    4251.1
    [m]
    C
    OD
    4255.1
    [m]
    C
    OD
    4259.8
    [m]
    C
    OD
    4263.7
    [m]
    C
    OD
    4266.0
    [m]
    C
    OD
    4266.0
    [m]
    C
    OD
    4270.4
    [m]
    C
    OD
    4272.0
    [m]
    C
    OD
    4272.0
    [m]
    C
    OD
    4272.3
    [m]
    C
    RRI
    4272.4
    [m]
    C
    OD
    4275.4
    [m]
    C
    OD
    4278.7
    [m]
    C
    RRI
    4278.7
    [m]
    C
    OD
    4281.9
    [m]
    C
    OD
    4284.6
    [m]
    C
    RRI
    4285.0
    [m]
    C
    OD
    4287.6
    [m]
    C
    OD
    4290.6
    [m]
    C
    OD
    4293.6
    [m]
    C
    OD
    4294.4
    [m]
    C
    RRI
    4296.5
    [m]
    C
    OD
    4299.9
    [m]
    C
    OD
    4302.2
    [m]
    C
    OD
    4304.7
    [m]
    C
    OD
    4305.6
    [m]
    C
    RRI
    4307.8
    [m]
    C
    OD

  • Thin sections at the Norwegian Offshore Directorate
    Thin sections at the Norwegian Offshore Directorate
    Depth
    Unit
    4285.55
    [m ]
    4291.00
    [m ]
    4295.94
    [m ]
    4300.00
    [m ]
    4306.80
    [m ]
    4098.05
    [m ]
    4104.05
    [m ]
    4118.05
    [m ]
    4137.22
    [m ]
    4170.70
    [m ]
    4187.67
    [m ]
    4205.90
    [m ]
    4239.64
    [m ]
    4253.00
    [m ]
    4261.12
    [m ]
    4270.97
    [m ]
    4281.56
    [m ]
    4082.16
    [m ]
    4089.40
    [m ]
    4095.10
    [m ]
    4186.55
    [m ]
    4256.80
    [m ]
    4275.00
    [m ]
    4175.75
    [m ]
    4282.25
    [m ]
    4195.50
    [m ]
    4190.65
    [m ]
    4277.70
    [m ]
    4302.80
    [m ]
    4084.25
    [m ]
    4131.00
    [m ]
    4169.95
    [m ]
    4130.60
    [m ]