Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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2/4-18 R

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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.
    2/4-18 R
    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
    Well name
    Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    2/4-18
    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.
    Saga Petroleum ASA
    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.
    762-L2
    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.
    142
    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,
    19.02.1994
    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.
    10.07.1994
    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.
    10.07.1996
    Plugged and abondon date
    Date when the P&A-operations of the wellbore was finished, as reported by the operator to the Norwegian Offshore Directorate throught DDRS (Daily Drilling Reporting System). Only applied once pr. wellhead/surface location.
    10.07.1994
    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.
    18.01.2007
    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.
    SHOWS
    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.
    42.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    68.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    5310.0
    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).
    5305.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    8.8
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    199
    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 JURASSIC
    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.
    FARSUND FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    56° 41' 59.91'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    3° 9' 46.05'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6284141.35
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    509969.18
    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.
    2253

  • Wellbore history
    General
    Well 2/4-18 R is located in the northern part of the block, on the eastern margin of the Feda Graben, Southern Norwegian North Sea. A number of wells originally operated by SAGA are located in this area on the Hidra Terrace, in the transition zone between the Hidra High-Steinbit Terrace to the NE, and the Feda Graben to the SW. The structural elements are separated by large NW-SE striking normal fault systems, forming series of rotated and downstepping terraces towards the axis of the Central Graben. The main objective of well was to test the reservoir potential of the Late Jurassic in a down-dip position with respect to previous wells 2/4-14 and 2/4-16. Secondary prospects were to be evaluated in the Late and Early Cretaceous. Planned TD was 5042 m +/- 150 m.
    Operations and results
    Well 2/4-18 R was spudded with the jack-up installation Maersk Guardian on19 February 1994 and drilled to TD at 5310 m in the Late Jurassic Farsund Formation. Drilling went without significant technical problems and close to the planned time schedule. The well was drilled with spud mud down to 521 m; with gel mud from 521 m to 1008 m; with pseudo oil based mud (Novadrill with poly-alpha-olefins from 1008 m to 3230 m, and with HI TEMP Polymer mud from 3230 m to TD.
    The well penetrated 3048 m of sediments confined to the Holocene-Eocene Nordland and Hordaland Groups. As in the previous wells in the area, the uppermost 900 m was composed of sand and clay. The rest was dominated by claystones with thin beds of limestone and sandstone. The Lowermost Eocene-Early Paleocene Rogaland Group proved a thickness of 193 m. The uppermost part was characteristically containing tuffaceous claystones. The middle part was dominated by claystones with traces of limestone/dolomite, whereas limestones and marls dominated the lower part. The Early Paleocene - Late Cretaceous Shetland Group had a thickness of 1113 m, and rested unconformable on the 252 m thick, Early Cretaceous Cromer Knoll Group. Chalky limestones and marls/claystones dominated the lithology, respectively. Weak hydrocarbon shows (limited porosity) was observed restricted zones in claystones of the Lista Formation and limestones in the lower part (i.e. not Ekofisk) Formation part of the Shetland Group.
    The well terminated 594 m into the Late Jurassic Tyne Group, nearly 300 m deeper than originally planned. Base Cretaceous Unconformity was identified 26 m shallower than expected. Expanded thicknesses and additional sequences were penetrated, and potential reservoir intervals were discovered deeper than expected. The interval was dominated by organic rich shales, and with downward increasing sandstone content, predominantly calcite cemented and in parts with traces of hydrocarbon shows. Vitrinite reflection measurements reveal that the shales of the Tyne Group are no longer oil generative in the well location, but are well into the gas generation window (%Ro = 1.1 to 1.7). Analyses of source richness in the Tyne Group show there are several claystones lithologies with highly variable hydrocarbon potentials. The dominating lithology is reported as a variably grey claystone with a very limited potential (TOC < 0.5%). Subordinate lithologies are generally darker. They are commonly coaly and/or silty and are found in zones in the Mandal Formation (TOC in the range 6 - 8 %), and in the Farsund Formation (TOC in the range 2 - 5 %).
    CPI data indicate net-pay hydrocarbon saturations in the order of 52% in an "Intra Farsund Sand" at 5137 to 5164 m. Several attempts of fluid sampling from 5150 m in this zone were unsuccessful. Sandstone beds below this level were water bearing and with a significantly higher pore pressure. Two conventional cores were cut in the Farsund Formation at 5105 m to 5114 m and at 5134 m to 5137.5 m.
    The well was permanently abandoned on 10 July as a well with strong shows.
    Testing
    No drill stem test was performed

  • 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]
    240.00
    5301.00

  • 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
    5134.0
    5137.2
    [m ]
    2
    5105.0
    5114.0
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    12.2
    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
    INTERM.
    18 5/8
    996.0
    26
    1005.0
    1.92
    LOT
    INTERM.
    13 3/8
    3219.0
    17 1/2
    3230.0
    1.87
    LOT
    INTERM.
    9 5/8
    4619.0
    12 1/4
    4632.0
    2.14
    LOT
    OPEN HOLE
    5310.0
    8 1/2
    5310.0
    0.00
    LOT

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    AS MSFL NGT AMS
    4620
    5202
    CBL VDL GR
    3219
    4625
    DLL MSFL AS LDT GR AMS
    3219
    4509
    DLL MSFL DSI GPIT NGT GR AMS
    4450
    4635
    FMI GR AMS
    3219
    4625
    FMS GR AMS
    4620
    5185
    LDT CNL CBL VDL GR AMS
    3219
    4550
    MDT GR AMS
    5100
    5310
    MSCT GR
    3219
    4625
    MSCT GR
    3219
    4625
    MWD - DIR
    232
    521
    MWD - DIR GR RES
    521
    3230
    PI LDT CNL NGT AMS
    4620
    5185
    RFT GR
    3561
    5110
    VELOCITY
    2890
    5110
    VSP
    3561
    5110

  • Lithostratigraphy

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    7.11

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    232
    1.05
    WATER BASED
    22.02.1994
    410
    1.10
    6.0
    20.0
    WATER BASED
    23.02.1994
    521
    1.10
    6.0
    20.0
    WATER BASED
    24.02.1994
    521
    1.10
    5.0
    20.0
    WATER BASED
    25.02.1994
    521
    1.10
    5.0
    20.0
    WATER BASED
    28.02.1994
    521
    1.10
    5.0
    20.0
    WATER BASED
    28.02.1994
    521
    1.09
    5.0
    20.0
    WATER BASED
    28.02.1994
    744
    1.20
    9.0
    20.0
    GEL MUD
    01.03.1994
    1008
    1.20
    8.0
    22.0
    GEL MUD
    03.03.1994
    1008
    1.40
    26.0
    11.0
    OIL BASED
    08.03.1994
    1008
    1.40
    26.0
    12.0
    OIL BASED
    08.03.1994
    1008
    1.20
    10.0
    17.0
    GEL MUD
    08.03.1994
    1030
    1.40
    23.0
    18.0
    OIL BASED
    08.03.1994
    1570
    1.50
    27.0
    24.0
    OIL BASED
    10.03.1994
    1893
    1.60
    35.0
    25.0
    OIL BASED
    10.03.1994
    1893
    1.60
    36.0
    28.0
    OIL BASED
    11.03.1994
    1893
    1.60
    38.0
    22.0
    OIL BASED
    14.03.1994
    1893
    1.60
    37.0
    30.0
    OIL BASED
    14.03.1994
    2947
    1.60
    37.0
    30.0
    OIL BASED
    14.03.1994
    2983
    1.60
    38.0
    18.0
    OIL BASED
    15.03.1994
    2983
    1.60
    38.0
    18.0
    OIL BASED
    16.03.1994
    2998
    1.60
    37.0
    19.0
    OIL BASED
    17.03.1994
    3190
    1.60
    37.0
    16.0
    OIL BASED
    18.03.1994
    3230
    1.60
    35.0
    15.0
    OIL BASED
    23.03.1994
    3230
    1.60
    35.0
    15.0
    OIL BASED
    22.03.1994
    3230
    1.60
    29.0
    13.0
    DUMMY
    24.03.1994
    3251
    1.60
    25.0
    10.0
    DUMMY
    25.03.1994
    3490
    1.61
    21.0
    11.0
    DUMMY
    05.04.1994
    3549
    1.61
    21.0
    10.0
    DUMMY
    05.04.1994
    3549
    1.60
    24.0
    11.0
    DUMMY
    29.03.1994
    3549
    1.61
    27.0
    13.0
    DUMMY
    30.03.1994
    3917
    1.61
    24.0
    11.0
    DUMMY
    05.04.1994
    3996
    1.60
    25.0
    12.0
    DUMMY
    05.04.1994
    4067
    1.60
    30.0
    12.0
    DUMMY
    05.04.1994
    4124
    1.60
    29.0
    11.0
    DUMMY
    05.04.1994
    4142
    1.60
    29.0
    11.0
    DUMMY
    06.04.1994
    4142
    1.61
    28.0
    12.0
    DUMMY
    07.04.1994
    4208
    1.60
    27.0
    11.0
    DUMMY
    08.04.1994
    4283
    1.60
    26.0
    11.0
    DUMMY
    11.04.1994
    4283
    1.60
    29.0
    12.0
    DUMMY
    11.04.1994
    4352
    1.60
    26.0
    9.0
    DUMMY
    11.04.1994
    4353
    1.60
    22.0
    9.0
    DUMMY
    12.04.1994
    4398
    1.60
    26.0
    9.0
    DUMMY
    14.04.1994
    4398
    1.62
    24.0
    9.0
    DUMMY
    14.04.1994
    4398
    1.62
    23.0
    9.0
    DUMMY
    18.04.1994
    4426
    1.62
    22.0
    9.0
    DUMMY
    18.04.1994
    4433
    1.62
    25.0
    10.0
    DUMMY
    18.04.1994
    4468
    1.64
    25.0
    9.0
    DUMMY
    18.04.1994
    4501
    1.64
    27.0
    10.0
    DUMMY
    19.04.1994
    4501
    1.66
    30.0
    11.0
    DUMMY
    21.04.1994
    4504
    1.66
    24.0
    10.0
    DUMMY
    21.04.1994
    4504
    1.66
    22.0
    9.0
    DUMMY
    22.04.1994
    4504
    1.66
    22.0
    9.0
    DUMMY
    25.04.1994
    4504
    1.66
    22.0
    9.0
    DUMMY
    25.04.1994
    4524
    1.66
    23.0
    8.0
    DUMMY
    25.04.1994
    4541
    1.68
    24.0
    10.0
    DUMMY
    26.04.1994
    4541
    1.68
    24.0
    9.0
    DUMMY
    27.04.1994
    4541
    1.68
    24.0
    10.0
    DUMMY
    28.04.1994
    4557
    1.68
    23.0
    11.0
    DUMMY
    29.04.1994
    4583
    1.74
    25.0
    10.0
    DUMMY
    02.05.1994
    4584
    1.75
    25.0
    8.0
    DUMMY
    02.05.1994
    4602
    1.76
    24.0
    11.0
    DUMMY
    02.05.1994
    4602
    1.76
    26.0
    10.0
    DUMMY
    03.05.1994
    4602
    1.76
    24.0
    10.0
    DUMMY
    04.05.1994
    4621
    1.76
    23.0
    11.0
    DUMMY
    05.05.1994
    4632
    1.82
    24.0
    8.0
    DUMMY
    09.05.1994
    4632
    0.00
    09.05.1994
    4632
    1.82
    22.0
    8.0
    DUMMY
    10.05.1994
    4632
    1.82
    21.0
    9.0
    DUMMY
    16.05.1994
    4632
    1.82
    21.0
    9.0
    DUMMY
    16.05.1994
    4632
    1.82
    22.0
    8.0
    DUMMY
    18.05.1994
    4632
    1.82
    21.0
    9.0
    DUMMY
    18.05.1994
    4632
    1.82
    21.0
    9.0
    DUMMY
    18.05.1994
    4635
    1.82
    19.0
    10.0
    DUMMY
    19.05.1994
    4635
    1.82
    25.0
    10.0
    DUMMY
    19.05.1994
    4651
    1.90
    21.0
    6.0
    DUMMY
    19.05.1994
    4687
    1.90
    28.0
    17.0
    DUMMY
    24.05.1994
    4711
    1.94
    32.0
    19.0
    DUMMY
    24.05.1994
    4711
    1.95
    31.0
    22.0
    DUMMY
    24.05.1994
    4746
    1.95
    33.0
    25.0
    DUMMY
    24.05.1994
    4804
    1.97
    31.0
    24.0
    DUMMY
    24.05.1994
    4804
    1.97
    35.0
    19.0
    DUMMY
    25.05.1994
    4804
    1.97
    29.0
    17.0
    DUMMY
    26.05.1994
    4832
    2.00
    31.0
    17.0
    DUMMY
    27.05.1994
    4832
    2.02
    17.0
    6.0
    DUMMY
    20.06.1994
    4832
    2.02
    18.0
    6.0
    DUMMY
    10.06.1994
    4832
    2.02
    17.0
    6.0
    DUMMY
    10.06.1994
    4832
    2.02
    18.0
    6.0
    DUMMY
    14.06.1994
    4832
    2.02
    17.0
    7.0
    DUMMY
    14.06.1994
    4832
    2.02
    19.0
    9.0
    DUMMY
    14.06.1994
    4832
    2.02
    20.0
    8.0
    DUMMY
    14.06.1994
    4832
    2.02
    20.0
    8.0
    DUMMY
    15.06.1994
    4832
    2.02
    16.0
    5.0
    DUMMY
    16.06.1994
    4832
    2.02
    17.0
    6.0
    DUMMY
    17.06.1994
    4832
    2.02
    17.0
    3.0
    DUMMY
    20.06.1994
    4832
    2.02
    17.0
    6.0
    DUMMY
    20.06.1994
    4832
    2.02
    18.0
    3.0
    DUMMY
    21.06.1994
    4832
    2.02
    18.0
    3.0
    DUMMY
    22.06.1994
    4832
    2.02
    18.0
    3.0
    DUMMY
    23.06.1994
    4832
    2.04
    17.0
    6.0
    DUMMY
    24.06.1994
    4832
    2.04
    17.0
    6.0
    DUMMY
    28.06.1994
    4867
    2.00
    32.0
    16.0
    DUMMY
    30.05.1994
    4897
    2.00
    28.0
    27.0
    DUMMY
    30.05.1994
    4930
    2.00
    22.0
    18.0
    DUMMY
    30.05.1994
    4930
    2.03
    23.0
    22.0
    DUMMY
    31.05.1994
    4944
    2.02
    21.0
    18.0
    DUMMY
    02.06.1994
    5001
    2.02
    22.0
    19.0
    DUMMY
    02.06.1994
    5041
    2.04
    21.0
    20.0
    DUMMY
    03.06.1994
    5041
    2.04
    23.0
    22.0
    DUMMY
    07.06.1994
    5105
    2.02
    17.0
    6.0
    DUMMY
    07.06.1994
    5105
    2.02
    17.0
    6.0
    DUMMY
    07.06.1994
    5114
    2.02
    16.0
    6.0
    DUMMY
    07.06.1994
    5114
    2.02
    17.0
    7.0
    DUMMY
    09.06.1994
    5221
    2.04
    17.0
    4.0
    DUMMY
    28.06.1994
    5221
    2.04
    20.0
    8.0
    DUMMY
    28.06.1994
    5221
    2.04
    21.0
    10.0
    DUMMY
    28.06.1994
    5221
    2.04
    20.0
    10.0
    DUMMY
    29.06.1994
    5221
    2.04
    26.0
    16.0
    DUMMY
    30.06.1994
    5221
    2.04
    25.0
    10.0
    DUMMY
    01.07.1994

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    4690.0
    [m]
    DC
    OD
    4700.0
    [m]
    DC
    OD
    4710.0
    [m]
    DC
    OD
    4719.0
    [m]
    DC
    OD
    4731.0
    [m]
    DC
    OD
    4749.0
    [m]
    DC
    OD
    4761.0
    [m]
    DC
    OD
    4779.0
    [m]
    DC
    OD
    4791.0
    [m]
    DC
    OD
    4803.0
    [m]
    DC
    OD
    4812.0
    [m]
    DC
    OD
    4821.0
    [m]
    DC
    OD
    4830.0
    [m]
    DC
    OD
    4839.0
    [m]
    DC
    OD
    4851.0
    [m]
    DC
    OD
    5037.0
    [m]
    DC
    OD
    5105.0
    [m]
    C
    OD
    5114.0
    [m]
    C
    OD
    5135.0
    [m]
    C
    OD
    5136.7
    [m]
    C
    OD
    5184.0
    [m]
    DC
    OD
    5190.0
    [m]
    DC
    OD
    5196.0
    [m]
    DC
    OD
    5202.0
    [m]
    DC
    OD
    5250.0
    [m]
    DC
    OD
    5301.0
    [m]
    DC
    OD