Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
12.11.2024 - 01:25
Time of last synchronization with Norwegian Offshore Directorate's internal systems

35/8-1

Export: PDF icon PDF

  • General information
    General information
    Attribute Value
    Wellbore name
    Official name of wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    35/8-1
    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
    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.
    35/8-1
    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.
    Norwegian Gulf Exploration Company AS
    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.
    258-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.
    182
    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,
    27.07.1980
    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.
    24.01.1981
    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.
    24.01.1983
    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.
    01.08.2010
    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/CONDENSATE
    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
    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.
    MIDDLE JURASSIC
    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.
    NESS 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.
    MIDDLE JURASSIC
    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.
    ETIVE FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    26.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    376.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4344.9
    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).
    4344.0
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    152
    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° 21' 26.37'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    3° 21' 44.09'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6802804.70
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    519372.88
    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.
    205

  • Wellbore history
    General
    Well 35/8-1 is located on the Marflo Spur, ca 30 km west of the Gjøa Field in the northern North Sea. The principal objective of this well was to test the hydrocarbon potential of sandstones within the Jurassic section beneath the Late Cimmerian Unconformity.
    Operations and results
    Wildcat well 35/8-1 was spudded with the semi-submersible installation Sedco-704 on 27 July 1980 and drilled to TD at 4345 m in Late Triassic sediments of the Statfjord Formation. The well was drilled without significant technical problems, but two well kicks occurred .After penetrating the Jurassic sand reservoir at 3516m a sudden rapid gas increase was noted, but due to mechanical problems could not be measured. This increase was associated with a quantity of reservoir fluids entering the borehole. During controlling of the kick, a large proportion of gas was vented and light low gravity yellowish oil recovered from the mud. A second kick with formation fluids entering the well bore was taken after coring core no 3 at 3549.6 to 3567.1 m. The well was drilled with seawater and viscous slugs down to 890 m, with gypsum/Lignosulphonate mud from 890 m to 2196 m, and with KCl/polymer mud from 2196 m to TD.
    The top sections down to Top Rogaland Group, Balder Formation at 1683 m contained a number of sands and sandy intervals. From top Rogaland and throughout the Cretaceous section down to top Draupne Formation at 3186 m the lithology was mainly claystone and limestone. The heather Formation came in at 3200 m with two thin Intra-Heather Formation sandstones at 3219 and 3250 m. Heather Formation shale continued down to the Brent Group at 3516 m. Frequent sandstones were penetrated in the Brent and Dunlin Groups, and in the Statfjord Formation.
    No shows or other hydrocarbon indications were recorded in the well above the first Intra Heather Formation sandstone at 3219 m. Indications of hydrocarbons while drilling occurred in Late, Middle and Early Jurassic sandstones. Log analysis indicated a gross hydrocarbon column of 140.5 m in the Brent Group down to a clear hydrocarbon/water contact at 3657 m in the Etive Formation. The gross hydrocarbon sand thickness was 115 m with an apparent net hydrocarbon thickness of 94 m. Average porosity in the net sand was 17% with an average water saturation of 25%. Apparent residual oil was indicated below the gas column in the Brent and in both Early Jurassic sands (Cook and Statfjord Formations). The Intra Heather Formation sandstones at 3219 and 3250 m were also interpreted as hydrocarbons based on shows and the logs.
    Thirteen cores, totalling 187 m, were cut in the Brent Sand reservoir from 3522.6 m to 3709.7 m. Coring continued until hydrocarbon shows were no longer encountered. RFT fluid samples were taken at at 3524 m (1.5 Sm3 gas + 2.15 litres 39 deg API oil + trace mud in suspension), 3524.5 m (ca 1.4 Sm3 gas + 1.3 litres 45.5 deg API oil + trace mud), 3637.5 m (2.1 Sm3 gas + 3.1 litres 43 deg API oil + trace mud), 3671 m (mud filtrate + "a grey brown cloudy liquid with sour odour" + trace of dissolved gas), 3576 m (9.8 litres mud filtrate with trace oil and small amount of gas), and at 3576.5 m (0.3 Sm3 gas + 0.35 litres 43 deg API oil + 1.4 litres mud filtrate). In addition to the RFT samples and samples taken during DST, samples with oil were recovered from the mud at 3515 m, 3518 m, and at 3567 m.
    The well was permanently abandoned on 24 June 1981 as a gas/condensate discovery
    Testing
    Two intervals in the Brent Group sands were tested.
    DST's no 1, 2, and 3 tested the interval 3636.3 to 3646.9 m in the Etive Formation. The two first DST's failed for technical reasons. DST3 gave flow rates of 650000 Sm3 gas, with 218 Sm3 condensate per day through a 40/64" choke. The Gas/condensate ratio was 2992 Sm3/Sm3, and the condensate gravity was 44.5 deg API. The H2S content was below detection and the gas stream contained only trace amounts of CO2. The maximum stable temperature recorded in DST3 was 134.4 deg C.
    DST4 tested the interval 3565.2 to 3578.0 m in the Tarbert Formation. It flowed 920000 Sm3 gas with 229 Sm3 condensate per day through a 48/64" choke. The Gas/condensate ratio was 4007 Sm3/Sm3, and the condensate gravity was 45.6 deg API. The gas stream contained traces of H2S and 1% CO2. Maximum temperature recorded in DST4 was 130.6 deg C.
    No water was produced in any of the tests.

  • Cuttings at the Norwegian Offshore Directorate
    Cuttings at the Norwegian Offshore Directorate
    Cuttings available for sampling?
    NO
    Cuttings at the Norwegian Offshore Directorate
    Cutting sample, top depth [m]
    Cutting samples, bottom depth [m]
    570.00
    4343.50

  • 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
    3522.6
    3528.7
    [m ]
    2
    3536.1
    3549.6
    [m ]
    3
    3549.6
    3567.1
    [m ]
    4
    3567.7
    3569.8
    [m ]
    5
    3569.8
    3587.3
    [m ]
    6
    3587.3
    3601.8
    [m ]
    7
    3602.4
    3610.4
    [m ]
    8
    3610.4
    3628.1
    [m ]
    9
    3628.1
    3647.3
    [m ]
    10
    3647.3
    3666.0
    [m ]
    11
    3666.0
    3671.9
    [m ]
    12
    3672.0
    3690.9
    [m ]
    13
    3690.9
    3709.7
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    178.4
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    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
    565.1
    36
    577.3
    0.00
    LOT
    SURF.COND.
    20
    877.5
    26
    890.0
    0.00
    LOT
    INTERM.
    13 3/8
    2184.6
    17 1/2
    2196.3
    1.65
    LOT
    INTERM.
    9 5/8
    3493.6
    12 1/4
    3522.6
    1.99
    LOT
    LINER
    7
    4343.7
    8 1/2
    4352.0
    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
    3636
    3645
    15.9
    2.0
    3636
    3645
    15.9
    3.0
    3636
    3645
    15.9
    4.0
    3565
    3575
    19.5
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    2.0
    3.0
    4.0
    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
    204
    651000
    0.804
    3197
    2.0
    204
    651000
    0.804
    3197
    3.0
    204
    651000
    0.804
    3197
    4.0
    229
    920000
    0.799
    0.656
    4070

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL
    2177
    3511
    DIPMETER
    2177
    3511
    FDC
    565
    736
    FDC CNL
    876
    2174
    FDC CNL
    2177
    3511
    HDT CYPER
    2177
    3511
    ISF SON
    565
    736
    ISF SON
    876
    2174
    ISF SON
    2177
    3511
    TEMP
    565
    736
    TEMP
    876
    2174

  • Lithostratigraphy

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    2.90
    pdf
    3.97
    pdf
    0.54
    pdf
    5.94

  • 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
    2.49
    pdf
    40.68

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    750
    1.08
    85.0
    WATER BASED
    1040
    1.13
    48.0
    WATER BASED
    2675
    1.21
    51.0
    WATER BASED
    2900
    1.29
    50.0
    WATER BASED
    3190
    1.34
    54.0
    WATER BASED
    3570
    1.74
    62.0
    WATER BASED

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    570.0
    [m]
    DC
    OD
    590.0
    [m]
    DC
    OD
    610.0
    [m]
    DC
    OD
    630.0
    [m]
    DC
    OD
    650.0
    [m]
    DC
    OD
    670.0
    [m]
    DC
    OD
    690.0
    [m]
    DC
    OD
    710.0
    [m]
    DC
    OD
    730.0
    [m]
    DC
    OD
    750.0
    [m]
    DC
    OD
    770.0
    [m]
    DC
    OD
    790.0
    [m]
    DC
    OD
    810.0
    [m]
    DC
    OD
    830.0
    [m]
    DC
    OD
    840.0
    [m]
    DC
    OD
    860.0
    [m]
    DC
    OD
    920.0
    [m]
    DC
    OD
    940.0
    [m]
    DC
    OD
    960.0
    [m]
    DC
    OD
    980.0
    [m]
    DC
    OD
    1000.0
    [m]
    DC
    OD
    1020.0
    [m]
    DC
    OD
    1040.0
    [m]
    DC
    OD
    1060.0
    [m]
    DC
    OD
    1080.0
    [m]
    DC
    OD
    1100.0
    [m]
    DC
    OD
    1120.0
    [m]
    DC
    OD
    1140.0
    [m]
    DC
    OD
    1160.0
    [m]
    DC
    OD
    1180.0
    [m]
    DC
    OD
    1200.0
    [m]
    DC
    OD
    1220.0
    [m]
    DC
    OD
    1240.0
    [m]
    DC
    OD
    1260.0
    [m]
    DC
    OD
    1280.0
    [m]
    DC
    OD
    1300.0
    [m]
    DC
    OD
    1320.0
    [m]
    DC
    OD
    1340.0
    [m]
    DC
    OD
    1360.0
    [m]
    DC
    OD
    1380.0
    [m]
    DC
    OD
    1400.0
    [m]
    DC
    OD
    1420.0
    [m]
    DC
    OD
    1440.0
    [m]
    DC
    OD
    1460.0
    [m]
    DC
    OD
    1480.0
    [m]
    DC
    OD
    1500.0
    [m]
    DC
    OD
    1520.0
    [m]
    DC
    OD
    1540.0
    [m]
    DC
    OD
    1560.0
    [m]
    DC
    OD
    1560.0
    [m]
    DC
    OD
    1580.0
    [m]
    DC
    OD
    1600.0
    [m]
    DC
    OD
    1620.0
    [m]
    DC
    OD
    1640.0
    [m]
    DC
    OD
    1660.0
    [m]
    DC
    OD
    1680.0
    [m]
    DC
    OD
    1700.0
    [m]
    DC
    OD
    1720.0
    [m]
    DC
    OD
    1740.0
    [m]
    DC
    OD
    1760.0
    [m]
    DC
    OD
    1780.0
    [m]
    DC
    OD
    1800.0
    [m]
    DC
    OD
    1820.0
    [m]
    DC
    OD
    1840.0
    [m]
    DC
    OD
    1860.0
    [m]
    DC
    OD
    1880.0
    [m]
    DC
    OD
    1900.0
    [m]
    DC
    OD
    1920.0
    [m]
    DC
    OD
    1940.0
    [m]
    DC
    OD
    1960.0
    [m]
    DC
    OD
    1980.0
    [m]
    DC
    OD
    2000.0
    [m]
    DC
    OD
    2020.0
    [m]
    DC
    OD
    2030.0
    [m]
    DC
    OD
    2040.0
    [m]
    DC
    OD
    2060.0
    [m]
    DC
    OD
    2080.0
    [m]
    DC
    OD
    2090.0
    [m]
    DC
    OD
    2100.0
    [m]
    DC
    OD
    2120.0
    [m]
    DC
    OD
    2140.0
    [m]
    DC
    OD
    2150.0
    [m]
    DC
    OD
    2160.0
    [m]
    DC
    OD
    2180.0
    [m]
    DC
    OD
    2200.0
    [m]
    DC
    OD
    2210.0
    [m]
    DC
    OD
    2220.0
    [m]
    DC
    OD
    2240.0
    [m]
    DC
    OD
    2260.0
    [m]
    DC
    OD
    2270.0
    [m]
    DC
    OD
    2280.0
    [m]
    DC
    OD
    2300.0
    [m]
    DC
    OD
    2320.0
    [m]
    DC
    OD
    2330.0
    [m]
    DC
    OD
    2340.0
    [m]
    DC
    OD
    2360.0
    [m]
    DC
    OD
    2380.0
    [m]
    DC
    OD
    2390.0
    [m]
    DC
    OD
    2400.0
    [m]
    DC
    OD
    2420.0
    [m]
    DC
    OD
    2440.0
    [m]
    DC
    OD
    2450.0
    [m]
    DC
    OD
    2460.0
    [m]
    DC
    OD
    2480.0
    [m]
    DC
    OD
    2500.0
    [m]
    DC
    OD
    2510.0
    [m]
    DC
    OD
    2520.0
    [m]
    DC
    OD
    2540.0
    [m]
    DC
    OD
    2560.0
    [m]
    DC
    OD
    2570.0
    [m]
    DC
    OD
    2580.0
    [m]
    DC
    OD
    2600.0
    [m]
    DC
    OD
    2620.0
    [m]
    DC
    OD
    2630.0
    [m]
    DC
    OD
    2635.0
    [m]
    DC
    OD
    2660.0
    [m]
    DC
    OD
    2680.0
    [m]
    DC
    OD
    2690.0
    [m]
    DC
    OD
    2700.0
    [m]
    DC
    OD
    2720.0
    [m]
    DC
    OD
    2740.0
    [m]
    DC
    OD
    2750.0
    [m]
    DC
    OD
    2760.0
    [m]
    DC
    OD
    2780.0
    [m]
    DC
    OD
    2800.0
    [m]
    DC
    OD
    2810.0
    [m]
    DC
    OD
    2820.0
    [m]
    DC
    OD
    2840.0
    [m]
    DC
    OD
    2860.0
    [m]
    DC
    OD
    2870.0
    [m]
    DC
    OD
    2880.0
    [m]
    DC
    OD
    2900.0
    [m]
    DC
    OD
    2920.0
    [m]
    DC
    OD
    2920.0
    [m]
    DC
    OD
    2940.0
    [m]
    DC
    OD
    2960.0
    [m]
    DC
    OD
    2980.0
    [m]
    DC
    OD
    3000.0
    [m]
    DC
    OD
    3020.0
    [m]
    DC
    OD
    3040.0
    [m]
    DC
    OD
    3060.0
    [m]
    DC
    OD
    3080.0
    [m]
    DC
    OD
    3085.0
    [m]
    DC
    OD
    3100.0
    [m]
    DC
    OD
    3120.0
    [m]
    DC
    OD
    3125.0
    [m]
    DC
    OD
    3140.0
    [m]
    DC
    OD
    3160.0
    [m]
    DC
    OD
    3165.0
    [m]
    DC
    OD
    3175.0
    [m]
    DC
    OD
    3180.0
    [m]
    DC
    OD
    3200.0
    [m]
    DC
    OD
    3213.0
    [m]
    DC
    OD
    3237.0
    [m]
    DC
    OD
    3255.0
    [m]
    DC
    OD
    3303.0
    [m]
    DC
    OD
    3321.0
    [m]
    DC
    OD
    3339.0
    [m]
    DC
    OD
    3360.0
    [m]
    DC
    OD
    3381.0
    [m]
    DC
    OD
    3399.0
    [m]
    DC
    OD
    3422.0
    [m]
    DC
    OD
    3423.0
    [m]
    DC
    OD
    3440.0
    [m]
    DC
    OD
    3441.0
    [m]
    DC
    OD
    3462.0
    [m]
    DC
    OD
    3483.0
    [m]
    DC
    OD
    3501.0
    [m]
    DC
    OD
    3522.8
    [m]
    C
    OD
    3527.7
    [m]
    C
    GEOSTRAT
    3531.5
    [m]
    C
    OD
    3538.0
    [m]
    C
    GEOSTRAT
    3541.4
    [m]
    C
    OD
    3544.0
    [m]
    C
    GEOSTRAT
    3550.1
    [m]
    C
    GEOSTR
    3551.8
    [m]
    C
    OD
    3558.6
    [m]
    C
    GEOSTRAT
    3562.8
    [m]
    C
    OD
    3567.4
    [m]
    C
    GEOSTRAT
    3571.9
    [m]
    C
    OD
    3578.2
    [m]
    C
    GEOSTRAT
    3581.4
    [m]
    C
    OD
    3589.9
    [m]
    C
    GEOSTRAT
    3591.8
    [m]
    C
    OD
    3599.8
    [m]
    C
    GEOSTRAT
    3601.0
    [m]
    C
    OD
    3611.0
    [m]
    C
    OD
    3615.6
    [m]
    C
    GEOSTRAT
    3620.5
    [m]
    C
    GEOSTR
    3621.7
    [m]
    C
    OD
    3626.5
    [m]
    C
    GEOSTRAT
    3632.4
    [m]
    C
    OD
    3636.5
    [m]
    C
    GEOSTRAT
    3643.4
    [m]
    C
    OD
    3651.5
    [m]
    C
    OD
    3654.0
    [m]
    C
    GEOSTRAT
    3661.3
    [m]
    C
    OD
    3669.5
    [m]
    C
    GEOSTRAT
    3669.8
    [m]
    C
    OD
    3680.7
    [m]
    C
    OD
    3691.5
    [m]
    C
    OD
    3701.8
    [m]
    C
    GEOSTRAT
    3702.7
    [m]
    C
    OD
    3704.5
    [m]
    C
    OD
    3720.0
    [m]
    DC
    OD
    3738.0
    [m]
    DC
    OD
    3762.0
    [m]
    DC
    OD
    3780.0
    [m]
    DC
    OD
    3800.0
    [m]
    DC
    OD
    3818.0
    [m]
    DC
    OD
    3840.0
    [m]
    DC
    OD
    3860.0
    [m]
    DC
    OD
    3882.0
    [m]
    DC
    OD
    3900.0
    [m]
    DC
    OD
    3920.0
    [m]
    DC
    OD
    3942.0
    [m]
    DC
    OD
    3962.0
    [m]
    DC
    OD
    3980.0
    [m]
    DC
    OD
    4000.0
    [m]
    DC
    OD
    4020.0
    [m]
    DC
    OD
    4042.0
    [m]
    DC
    OD
    4060.0
    [m]
    DC
    OD
    4080.0
    [m]
    DC
    OD
    4102.0
    [m]
    DC
    OD
    4120.0
    [m]
    DC
    OD
    4140.0
    [m]
    DC
    OD
    4162.0
    [m]
    DC
    OD
    4182.0
    [m]
    DC
    OD
    4200.0
    [m]
    DC
    OD
    4222.0
    [m]
    DC
    OD
    4222.0
    [m]
    DC
    OD
    4240.0
    [m]
    DC
    OD
    4260.0
    [m]
    DC
    OD
    4280.0
    [m]
    DC
    OD
    4300.0
    [m]
    DC
    OD

  • Thin sections at the Norwegian Offshore Directorate
    Thin sections at the Norwegian Offshore Directorate
    Depth
    Unit
    3639.70
    [m ]
    3532.60
    [m ]
    3523.47
    [m ]
    3647.00
    [m ]
    3527.60
    [m ]
    3680.95
    [m ]
    3643.40
    [m ]
    3632.00
    [m ]
    3685.45
    [m ]
    3671.35
    [m ]