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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15/12-6 S

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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.
    15/12-6 S
    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.
    RE-CLASS TO DEV
    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.
    15/12-6
    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.
    644-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.
    78
    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,
    19.08.1990
    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.
    04.11.1990
    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.
    04.11.1992
    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.
    15.08.2008
    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
    Reclassified to wellbore
    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
    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
    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 HEATHER FM SS
    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.
    84.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3050.0
    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).
    3034.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    11.7
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    128
    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.
    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.
    58° 4' 40.3'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    1° 53' 25.41'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6438063.13
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    434552.91
    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.
    1524

  • Wellbore history
    Block 15/12 is situated between the Jæren High to the south, Central Graben to the south-southwest, Andrew Ridge to the west, Ling Graben to the north and Viking Graben to the north-northwest. Well 15/12-6 S was the third well within the license area. It was drilled ca 3 km north of the 15/12-4 Varg Discovery well, which found 1.5 oil column in Jurassic sandstone. The main objective of 15/12-6 S was to test the hydrocarbon potential in Oxfordian sandstone in the north-western segment of the Beta west structure. Secondary objectives were Palaeocene sandstones (Maureen formation) and Triassic sandstones. Due to possible shallow gas problems, the well was moved 100 south to avoid this problem.
    Operations and results
    Well 15/12-6 S was spudded 19 August 1990 with the semi-submersible rig Deepsea Bergen and drilled to 3050 m in the Triassic Skagerrak Formation. While drilling the 12 1/4" hole the penetration stopped at 2560 m. The BHA was pulled out and it was found that the MWD tool had been twisted off. The hole was cemented back and sidetracked from 2495 m with increased mud weight. Ran 7" liner to 3046 m, and cemented inside the liner to 2960 m. No shallow gas was encountered. The well was drilled with bentonite spud mud and CMC/seawater down to 615 m, with gypsum/polymer mud from 615 m to 2757 m, and with gel/lignosulphonate mud from 2757 m to TD.
    Logs and shows indicated presence of hydrocarbons in the interval from 2428 to 2473 m in the late Cretaceous chalk but tests were not performed here due to tight formation. The Late Jurassic Oxfordian sandstone (Hugin Formation) came in at 2871 m, 80.5 m deeper than prognosed. It contained oil and from logs the OWC was found to be at 2943 m. There were no shows or other hydrocarbon indications below this depth.
    A total of seven cores were cut, six in the interval 2838 to 2966 m and the seventh from 2980 to 2988.5 m. An FMT run in Oxfordian sandstone gave 12 pressure readings out of 27 attempts. One sample was taken at 2935.5 m. The sample contained a mixture of mud filtrate and formation water with traces of hydrocarbons.
    The well was suspended on 4 November 1990 as an oil appraisal well, and was converted to development well (15/12-A-2).
    Testing
    Two DST tests were performed in this well:
    DST 1 from 2922 - 2930 m produced 153.8 Sm3/d oil and 11.683 Sm3/d gas through a 12.7 mm choke. The GOR was 76 Sm3/Sm3. A breakthrough, possibly through a fault, occurred at the end of the cleanup flow in this test, and this totally changed well productivity and also altered the flowing temperature. Before the breakthrough the temperature was 127 deg C and still increasing. After breakthrough the temperature sunk to 123 deg C.
    DST 2 from 2875 - 2895 m produced 866 Sm3/d oil and 52530 Sm3/d gas through a 15.9 mm choke. The GOR was 61 Sm3/Sm3, the oil density was 0.843 g/cm3 and the gas gravity was 0.740 (air = 1). The reservoir temperature was measured to 127.5 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]
    620.00
    2787.00

  • 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
    2838.0
    2864.6
    [m ]
    2
    2865.0
    2891.8
    [m ]
    3
    2892.0
    2907.9
    [m ]
    4
    2910.0
    2937.4
    [m ]
    5
    2937.6
    2953.0
    [m ]
    6
    2953.0
    2964.4
    [m ]
    7
    2980.0
    2988.3
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    131.8
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 2838-2843m
    Core photo at depth: 2848-2853m
    Core photo at depth: 2853-2858m
    Core photo at depth: 2858-2863m
    Core photo at depth: 2863-2864m
    2838-2843m
    2848-2853m
    2853-2858m
    2858-2863m
    2863-2864m
    Core photo at depth: 2865-2870m
    Core photo at depth: 2870-2875m
    Core photo at depth: 2875-2880m
    Core photo at depth: 2880-2885m
    Core photo at depth: 2885-2890m
    2865-2870m
    2870-2875m
    2875-2880m
    2880-2885m
    2885-2890m
    Core photo at depth: 2890-2891m
    Core photo at depth: 2892-2897m
    Core photo at depth: 2897-2902m
    Core photo at depth: 2902-2907m
    Core photo at depth: 2907-2908m
    2890-2891m
    2892-2897m
    2897-2902m
    2902-2907m
    2907-2908m
    Core photo at depth: 2910-2915m
    Core photo at depth: 2915-2910m
    Core photo at depth: 2920-2925m
    Core photo at depth: 2925-2930m
    Core photo at depth: 2930-2935m
    2910-2915m
    2915-2910m
    2920-2925m
    2925-2930m
    2930-2935m
    Core photo at depth: 2935-2937m
    Core photo at depth: 2937-2942m
    Core photo at depth: 2942-2947m
    Core photo at depth: 2947-2952m
    Core photo at depth: 2952-2953m
    2935-2937m
    2937-2942m
    2942-2947m
    2947-2952m
    2952-2953m
    Core photo at depth: 2953-2958m
    Core photo at depth: 2958-2963m
    Core photo at depth: 2963-2964m
    Core photo at depth: 2980-2985m
    Core photo at depth: 2985-2988m
    2953-2958m
    2958-2963m
    2963-2964m
    2980-2985m
    2985-2988m

  • 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
    2922.00
    2930.00
    13.10.1990 - 20:00
    YES
    DST
    TEST2
    2875.00
    2895.00
    24.10.1990 - 19:30
    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
    167.0
    36
    167.0
    0.00
    LOT
    INTERM.
    20
    599.0
    26
    615.0
    1.56
    LOT
    INTERM.
    13 3/8
    1700.0
    17 1/2
    1715.0
    1.82
    LOT
    INTERM.
    9 5/8
    2743.0
    12 1/4
    2757.0
    1.97
    LOT
    LINER
    7
    3046.0
    8 1/2
    3050.0
    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
    2922
    2930
    12.7
    2.0
    2875
    2895
    15.9
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    10.000
    123
    2.0
    8.000
    127
    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
    154
    11683
    0.850
    0.795
    76
    2.0
    866
    52530
    0.843
    0.740
    61

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    ACBL VDL GR
    95
    1701
    ACBL VDL GR
    1450
    2926
    CDL CNL GR CAL
    2345
    2756
    DIFL AC SP GR
    2742
    3048
    DIFL ACL SP GR
    1699
    2756
    DIPLOG GR
    2401
    2755
    DIPLOG GR
    2743
    3049
    FMT GR
    2429
    2470
    FMT HP GR
    2976
    3032
    MLL DLL GR
    2742
    3019
    MWD - GR RES DIR
    170
    3090
    SP
    2742
    3049
    VELOCITY
    500
    3050
    ZDL CN SL
    2742
    3049

  • Lithostratigraphy

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.50
    pdf
    0.15
    pdf
    1.96

  • 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
    2.12
    pdf
    13.79

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    615
    0.00
    WATER BASED
    23.08.1990
    615
    1.03
    DUMMY
    27.08.1990
    618
    1.15
    15.0
    5.0
    WATER BASED
    27.08.1990
    1355
    1.15
    21.0
    5.5
    WATER BASED
    27.08.1990
    1710
    1.30
    21.0
    5.5
    WATER BASED
    28.08.1990
    1710
    1.30
    23.0
    6.5
    WATER BASED
    29.08.1990
    1710
    1.30
    23.0
    6.0
    WATER BASED
    30.08.1990
    1710
    1.30
    22.0
    6.0
    WATER BASED
    31.08.1990
    1851
    1.40
    20.0
    6.0
    WATER BASED
    04.09.1990
    2155
    1.40
    20.0
    6.0
    WATER BASED
    04.09.1990
    2200
    1.50
    22.0
    6.5
    WATER BASED
    04.09.1990
    2310
    1.50
    23.0
    6.0
    WATER BASED
    04.09.1990
    2310
    1.50
    23.0
    6.0
    WATER BASED
    05.09.1990
    2310
    1.50
    23.0
    6.5
    WATER BASED
    06.09.1990
    2310
    1.55
    23.0
    6.5
    WATER BASED
    07.09.1990
    2310
    1.55
    23.0
    7.0
    WATER BASED
    10.09.1990
    2310
    1.50
    22.0
    6.5
    WATER BASED
    04.09.1990
    2310
    1.55
    23.0
    6.0
    WATER BASED
    10.09.1990
    2310
    1.58
    23.0
    8.0
    WATER BASED
    14.09.1990
    2310
    1.61
    25.0
    10.0
    WATER BASED
    17.09.1990
    2310
    1.61
    26.0
    9.5
    WATER BASED
    17.09.1990
    2310
    1.61
    24.0
    10.0
    WATER BASED
    18.09.1990
    2310
    1.61
    25.0
    10.0
    WATER BASED
    17.09.1990
    2310
    1.55
    23.0
    6.0
    WATER BASED
    10.09.1990
    2310
    1.55
    23.0
    7.0
    WATER BASED
    13.09.1990
    2345
    1.50
    23.0
    6.0
    WATER BASED
    04.09.1990
    2474
    1.50
    22.0
    6.5
    WATER BASED
    04.09.1990
    2495
    1.55
    23.0
    6.5
    WATER BASED
    07.09.1990
    2511
    1.55
    23.0
    7.0
    WATER BASED
    10.09.1990
    2520
    1.55
    23.0
    6.0
    WATER BASED
    10.09.1990
    2560
    1.50
    23.0
    6.5
    WATER BASED
    06.09.1990
    2560
    1.50
    23.0
    6.0
    WATER BASED
    05.09.1990
    2587
    1.55
    23.0
    6.0
    WATER BASED
    10.09.1990
    2743
    1.32
    15.0
    4.0
    WATER BASED
    25.09.1990
    2743
    1.32
    28.0
    4.0
    WATER BASED
    05.10.1990
    2743
    1.32
    30.0
    5.0
    WATER BASED
    08.10.1990
    2743
    1.32
    28.0
    5.0
    WATER BASED
    08.10.1990
    2743
    1.32
    28.0
    4.5
    WATER BASED
    08.10.1990
    2743
    1.32
    24.0
    5.0
    WATER BASED
    26.09.1990
    2743
    1.32
    22.0
    5.0
    WATER BASED
    27.09.1990
    2743
    1.32
    24.0
    4.0
    WATER BASED
    01.10.1990
    2743
    1.32
    28.0
    5.0
    WATER BASED
    01.10.1990
    2743
    1.32
    23.0
    5.0
    WATER BASED
    26.09.1990
    2743
    1.32
    28.0
    4.0
    WATER BASED
    01.10.1990
    2743
    1.32
    21.0
    4.0
    WATER BASED
    01.10.1990
    2743
    1.32
    21.0
    4.0
    WATER BASED
    02.10.1990
    2743
    1.32
    26.0
    4.0
    WATER BASED
    03.10.1990
    2743
    1.32
    28.0
    4.0
    WATER BASED
    04.10.1990
    2757
    1.61
    26.0
    9.5
    WATER BASED
    17.09.1990
    2757
    1.61
    24.0
    10.0
    WATER BASED
    18.09.1990
    2757
    1.61
    25.0
    10.0
    WATER BASED
    17.09.1990
    2757
    1.61
    25.0
    10.0
    WATER BASED
    20.09.1990
    2757
    1.61
    25.0
    10.0
    WATER BASED
    20.09.1990
    2757
    1.61
    26.0
    10.0
    WATER BASED
    21.09.1990
    2757
    1.61
    26.0
    10.0
    WATER BASED
    24.09.1990
    2757
    1.61
    26.0
    10.0
    WATER BASED
    25.09.1990
    2757
    1.55
    23.0
    7.0
    WATER BASED
    13.09.1990
    2757
    1.61
    25.0
    10.0
    WATER BASED
    17.09.1990
    2757
    1.58
    23.0
    8.0
    WATER BASED
    14.09.1990
    2830
    1.32
    15.0
    4.0
    WATER BASED
    25.09.1990
    2865
    1.32
    23.0
    5.0
    WATER BASED
    26.09.1990
    2876
    1.32
    28.0
    4.0
    WATER BASED
    05.10.1990
    2876
    1.32
    28.0
    5.0
    WATER BASED
    08.10.1990
    2876
    1.32
    30.0
    5.0
    WATER BASED
    08.10.1990
    2876
    1.32
    28.0
    4.5
    WATER BASED
    08.10.1990
    2910
    1.32
    24.0
    5.0
    WATER BASED
    26.09.1990
    2952
    1.32
    22.0
    5.0
    WATER BASED
    27.09.1990
    2966
    1.32
    24.0
    4.0
    WATER BASED
    01.10.1990
    2985
    1.32
    28.0
    4.0
    WATER BASED
    01.10.1990
    2985
    1.32
    28.0
    5.0
    WATER BASED
    01.10.1990
    2985
    1.32
    21.0
    4.0
    WATER BASED
    02.10.1990
    2985
    1.32
    21.0
    4.0
    WATER BASED
    01.10.1990
    3019
    1.32
    26.0
    4.0
    WATER BASED
    03.10.1990
    3050
    1.32
    28.0
    4.0
    WATER BASED
    04.10.1990
    3050
    1.32
    30.0
    5.0
    WATER BASED
    08.10.1990
    3050
    1.32
    28.0
    4.0
    WATER BASED
    05.10.1990
    3050
    1.32
    28.0
    5.0
    WATER BASED
    08.10.1990
    3050
    1.32
    28.0
    4.5
    WATER BASED
    08.10.1990

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1250.0
    [m]
    DC
    GEOCH
    1270.0
    [m]
    DC
    GEOCH
    1280.0
    [m]
    DC
    GEOCH
    1300.0
    [m]
    DC
    GEOCH
    1310.0
    [m]
    DC
    GEOCH
    1330.0
    [m]
    DC
    GEOCH
    1340.0
    [m]
    DC
    GEOCH
    1360.0
    [m]
    DC
    GEOCH
    1370.0
    [m]
    DC
    GEOCH
    1390.0
    [m]
    DC
    GEOCH
    1400.0
    [m]
    DC
    GEOCH
    1420.0
    [m]
    DC
    GEOCH
    1430.0
    [m]
    DC
    GEOCH
    1450.0
    [m]
    DC
    GEOCH
    1460.0
    [m]
    DC
    GEOCH
    1480.0
    [m]
    DC
    GEOCH
    1490.0
    [m]
    DC
    GEOCH
    1510.0
    [m]
    DC
    GEOCH
    1520.0
    [m]
    DC
    GEOCH
    1540.0
    [m]
    DC
    GEOCH
    1550.0
    [m]
    DC
    GEOCH
    1570.0
    [m]
    DC
    GEOCH
    1580.0
    [m]
    DC
    GEOCH
    1600.0
    [m]
    DC
    GEOCH
    1610.0
    [m]
    DC
    GEOCH
    1630.0
    [m]
    DC
    GEOCH
    1640.0
    [m]
    DC
    GEOCH
    1660.0
    [m]
    DC
    GEOCH
    1670.0
    [m]
    DC
    GEOCH
    1690.0
    [m]
    DC
    GEOCH
    1700.0
    [m]
    DC
    GEOCH
    1715.0
    [m]
    DC
    GEOCH
    1730.0
    [m]
    DC
    GEOCH
    1750.0
    [m]
    DC
    GEOCH
    1760.0
    [m]
    DC
    GEOCH
    1780.0
    [m]
    DC
    GEOCH
    1790.0
    [m]
    DC
    GEOCH
    1810.0
    [m]
    DC
    GEOCH
    1820.0
    [m]
    DC
    GEOCH
    1840.0
    [m]
    DC
    GEOCH
    1850.0
    [m]
    DC
    GEOCH
    1870.0
    [m]
    DC
    GEOCH
    1880.0
    [m]
    DC
    GEOCH
    1900.0
    [m]
    DC
    GEOCH
    1910.0
    [m]
    DC
    GEOCH
    1930.0
    [m]
    DC
    GEOCH
    1940.0
    [m]
    DC
    GEOCH
    1951.0
    [m]
    SWC
    STATOIL
    1960.0
    [m]
    DC
    GEOCHEM
    1970.0
    [m]
    DC
    GEOCHE
    1990.0
    [m]
    DC
    GEOCHE
    2000.0
    [m]
    DC
    GEOCHE
    2020.0
    [m]
    DC
    GEOCHE
    2030.0
    [m]
    DC
    GEOCHE
    2050.0
    [m]
    DC
    GEOCHE
    2060.0
    [m]
    DC
    GEOCHE
    2080.0
    [m]
    DC
    GEOCHE
    2110.0
    [m]
    DC
    GEOCHE
    2120.0
    [m]
    DC
    GEOCHE
    2140.0
    [m]
    DC
    GEOCHE
    2150.0
    [m]
    DC
    GEOCHE
    2170.0
    [m]
    DC
    GEOCHE
    2180.0
    [m]
    DC
    GEOCHE
    2200.0
    [m]
    DC
    GEOCHE
    2210.0
    [m]
    DC
    GEOCHE
    2230.0
    [m]
    DC
    GEOCHE
    2240.0
    [m]
    DC
    GEOCHE
    2260.0
    [m]
    DC
    GEOCHE
    2270.0
    [m]
    DC
    GEOCHE
    2290.0
    [m]
    DC
    GEOCHE
    2300.0
    [m]
    DC
    GEOCHE
    2306.0
    [m]
    DC
    GEOCHE
    2310.0
    [m]
    SWC
    STATOIL
    2318.0
    [m]
    DC
    GEOCHEM
    2324.0
    [m]
    DC
    GEOCHE
    2342.0
    [m]
    DC
    GEOCHE
    2360.0
    [m]
    DC
    GEOCHE
    2372.0
    [m]
    DC
    GEOCHE
    2384.0
    [m]
    DC
    GEOCHE
    2402.0
    [m]
    DC
    GEOCHE
    2417.0
    [m]
    DC
    GEOCHE
    2417.0
    [m]
    SWC
    STATOIL
    2426.0
    [m]
    DC
    GEOCHEM
    2432.0
    [m]
    DC
    GEOCHE
    2736.0
    [m]
    SWC
    STATOIL
    2747.5
    [m]
    SWC
    STATOI
    2755.0
    [m]
    SWC
    STATOI
    2761.3
    [m]
    SWC
    STATOI
    2768.5
    [m]
    SWC
    STATOI
    2780.5
    [m]
    SWC
    STATOI
    2787.5
    [m]
    SWC
    STATOI
    2791.5
    [m]
    SWC
    STATOI
    2803.5
    [m]
    SWC
    STATOI
    2810.9
    [m]
    SWC
    STATOI
    2821.9
    [m]
    SWC
    STATOI
    2835.5
    [m]
    SWC
    STATOI
    2839.2
    [m]
    C
    STATOI
    2840.5
    [m]
    C
    2840.6
    [m]
    C
    2845.2
    [m]
    C
    STATOIL
    2845.2
    [m]
    C
    STATOI
    2849.5
    [m]
    C
    2850.5
    [m]
    C
    STATOIL
    2856.5
    [m]
    C
    STATOI
    2861.7
    [m]
    C
    STATOI
    2866.3
    [m]
    C
    STATOI
    2868.5
    [m]
    C
    2868.6
    [m]
    C
    STATOIL
    2869.5
    [m]
    C
    2871.4
    [m]
    C
    STATOIL
    2871.5
    [m]
    C
    2887.3
    [m]
    C
    STATOIL
    2896.4
    [m]
    C
    STATOI
    2899.1
    [m]
    C
    2900.8
    [m]
    C
    STATOIL
    2901.5
    [m]
    C
    STATOI
    2912.5
    [m]
    C
    2913.5
    [m]
    C
    2913.6
    [m]
    C
    STATOIL
    2926.3
    [m]
    C
    STATOI
    2929.5
    [m]
    C
    STATOI
    2936.5
    [m]
    C
    2936.7
    [m]
    C
    STATOIL
    2942.7
    [m]
    C
    STATOI
    2943.7
    [m]
    C
    STATOI
    2947.4
    [m]
    C
    STATOI
    2947.4
    [m]
    C
    2950.2
    [m]
    C
    STATOIL
    2951.0
    [m]
    C
    STATOI
    2951.8
    [m]
    C
    STATOI
    2953.9
    [m]
    C
    STATOI
    2957.2
    [m]
    C
    STATOI
    2960.0
    [m]
    C
    STATOI
    2986.2
    [m]
    C
    STATOI
    3047.0
    [m]
    SWC
    STATOI

  • Thin sections at the Norwegian Offshore Directorate
    Thin sections at the Norwegian Offshore Directorate
    Depth
    Unit
    2892.20
    [m ]
    2892.80
    [m ]