Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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25.11.2024 - 01:30
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6407/1-2

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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.
    6407/1-2
    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
    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.
    NORWEGIAN 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.
    6407/1-2
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    8110 - 427 SP 234
    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.
    355-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.
    184
    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,
    13.11.1982
    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.
    15.05.1983
    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.
    15.05.1985
    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.
    13.12.2005
    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
    Reentry
    Status whether the wellbore has been re-entered (YES) or not (NO). Re-entered wellbores are not included in the count when wellbores are presented in statistical overviews.
    NO
    Content
    For exploration wellbores, status of discovery.

    Legal values:
    DRY, SHOWS (trace amounts of hydrocarbons), GAS, GAS/CONDENSATE, OIL or OIL/GAS.
    SHOWS (GAS SHOWS, OIL SHOWS or OIL/GAS SHOWS) are detected as fluorescent cut (organic extract), petroleum odour, or visual stain on cuttings or cores, or as increased gas reading on the mud-loggers gas detection equipment.
    Legal values for WILDCAT-CCS and APPRAISAL-CCS: WATER

    For development wellbores, type of produced/injected fluid.
    Legal values:
    WATER, CUTTINGS, NOT AVAILABLE, OIL, GAS/CONDENSATE, OIL/GAS, CO2, GAS, WATER/GAS, NOT APPLICABLE.
    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.
    GARN 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.
    273.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4560.0
    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).
    4558.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    5
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    159
    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.
    GREY BEDS (INFORMAL)
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    64° 47' 50.61'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    7° 2' 23.76'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7187495.23
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    406877.13
    UTM zone
    Universal Transverse Mercator zone. Examples of legal values: 31, 32, 33, 34.
    32
    NPDID wellbore
    Norwegian Offshore Directorate's unique id for the wellbore.
    61

  • Wellbore history
    General
    The wildcat 6407/1-2 was drilled 43 m NW of well 6407/1-1, which was drilled to 900 m before it was junked due to problems with setting the 20" casing. The objective for both wells was to test for hydrocarbons in Jurassic sandstones. The primary target was Middle Jurassic sand horizons, Early Jurassic sands was secondary target. The well was the first well north of 62 degrees to encounter liquid petroleum.
    The well is Type Well for the Kai Formation and Reference Well for the Nordland Group. It is Reference Well for the Lyr Formation, the Fangst Group, and the BÅt Group
    Operations and results
    Wildcat well 6407/1-2 was spudded with the semi-submersible installation Dyvi Delta on 13 November 1982 and drilled to TD at 4560 m in the Late Triassic Grey Beds. The well was drilled with seawater/gel down to 901 m, with gypsum/lignosulphonate from 901 m to 3568 m, and with Spersene/XP-20/resin from 3568 m to TD. At 1817 m loss of mud to the formation was discovered. A survey showed that this was caused by a collapse of 20" casing from approximately 667 m. It was therefore decided to run the 13 3/8" casing at this point. A total of 164 days were spent on the drilling phase, which was 56 days more than prognosed. 22 days were lost due to bad weather, 17 days due to BOP problems, 4 days working with the collapsed 20" casing, 7 days were spent on fishing when the drill string parted. A further 12 days were spent on excessive reaming in the 12 1/4" hole in the Paleocene and top of the Cretaceous formation, and in the 8 1/2" hole in the Heather formation. The reaming was necessary when running back in hole after several days WOW with the BOP closed and the riser disconnected. The well was drilled 60 meters deeper than prognosed. The testing phase lasted for 21 days, which includes a 7" casing tie back operation of 6 days, which was necessary because of a leak in the 9 5/8" at approximately 1850 m. The budget for the well 6407/1-1 was NOK 100 MM. The total cost of the 6407/1-1 and the 6407/1-2 were NOK 204.5 MM for the drilling phase. The cost of the testing phase was NOK 28.3 MM.
    Hydrocarbons were found in the Middle Jurassic sandstone, Garn Formation from 3659 m down to a well-defined gas-water contact at 3716 m. The secondary objective was found to be water wet but hydrocarbon shows were recorded in the Early Jurassic Tilje and Åre Formations. The shows became stronger below 4300 m and downwards, with increasing gas shows towards TD.
    Four cores were cut in the Middle Jurassic sequence. RFT pressure points were obtained for both target reservoir sections. A RFT segregated fluid sample was taken at 3665 m in the Garn Formation
    The well was permanently abandoned on 15 May 1983 as a gas/condensate discovery
    Testing
    One drill stem test was performed from the interval 3659 m to 3669 m in the Garn Formation. The test produced 454 Sm3 condensate and 394000 Sm3 gas per day during the main flow, on a 19 mm choke. The gas/condensate ratio was 869 Sm3/Sm3. The test also produced 3% CO2 and 6 - 7 ppm of H2S. The reservoir fluid was a gas condensate near the critical point.

  • 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]
    410.00
    4560.00

  • 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
    3661.0
    3678.3
    [m ]
    2
    3679.0
    3688.5
    [m ]
    3
    3688.5
    3701.0
    [m ]
    4
    3701.5
    3719.3
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    57.1
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 3661-3668m
    Core photo at depth: 3668-3675m
    Core photo at depth: 3675-3678m
    Core photo at depth: 3679-3686m
    Core photo at depth: 3686-3688m
    3661-3668m
    3668-3675m
    3675-3678m
    3679-3686m
    3686-3688m
    Core photo at depth: 3688-3695m
    Core photo at depth: 3695-3701m
    Core photo at depth: 3701-3708m
    Core photo at depth: 3708-3715m
    Core photo at depth: 3715-3719m
    3688-3695m
    3695-3701m
    3701-3708m
    3708-3715m
    3715-3719m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1975.0
    [m]
    SWC
    LAP
    2120.0
    [m]
    DC
    LAP
    2130.0
    [m]
    DC
    LAP
    2140.0
    [m]
    DC
    LAP
    2160.0
    [m]
    DC
    LAP
    2180.0
    [m]
    DC
    LAP
    2191.5
    [m]
    SWC
    LAP
    2200.0
    [m]
    DC
    LAP
    2215.0
    [m]
    SWC
    LAP
    2220.0
    [m]
    DC
    LAP
    2232.0
    [m]
    SWC
    LAP
    2240.0
    [m]
    DC
    LAP
    2260.0
    [m]
    DC
    LAP
    2269.0
    [m]
    SWC
    LAP
    2280.0
    [m]
    DC
    LAP
    2281.0
    [m]
    SWC
    LAP
    2290.2
    [m]
    SWC
    LAP
    2300.0
    [m]
    DC
    LAP
    2320.0
    [m]
    DC
    LAP
    2327.5
    [m]
    SWC
    LAP
    2330.0
    [m]
    DC
    LAP
    2330.5
    [m]
    SWC
    LAP
    2340.0
    [m]
    DC
    LAP
    2347.5
    [m]
    SWC
    LAP
    2360.0
    [m]
    DC
    LAP
    2370.0
    [m]
    DC
    LAP
    2380.0
    [m]
    DC
    LAP
    2400.0
    [m]
    DC
    LAP
    2420.0
    [m]
    DC
    LAP
    2440.0
    [m]
    DC
    LAP
    2454.1
    [m]
    SWC
    LAP
    2460.0
    [m]
    DC
    LAP
    2461.3
    [m]
    SWC
    LAP
    2480.0
    [m]
    DC
    LAP
    2490.9
    [m]
    SWC
    LAP
    2500.0
    [m]
    DC
    LAP
    2520.0
    [m]
    DC
    LAP
    2522.0
    [m]
    SWC
    LAP
    2540.0
    [m]
    DC
    LAP
    2540.2
    [m]
    SWC
    LAP
    2560.0
    [m]
    DC
    LAP
    2570.0
    [m]
    DC
    LAP
    2580.0
    [m]
    DC
    LAP
    2590.0
    [m]
    DC
    LAP
    2600.0
    [m]
    DC
    LAP
    2601.2
    [m]
    SWC
    LAP
    2610.0
    [m]
    DC
    LAP
    2620.0
    [m]
    DC
    LAP
    2630.0
    [m]
    DC
    LAP
    2639.1
    [m]
    SWC
    LAP
    2640.0
    [m]
    DC
    LAP
    2650.0
    [m]
    DC
    LAP
    2660.0
    [m]
    DC
    LAP
    2670.0
    [m]
    DC
    LAP
    2680.0
    [m]
    DC
    LAP
    2687.0
    [m]
    SWC
    LAP
    2700.0
    [m]
    DC
    LAP
    2710.0
    [m]
    DC
    LAP
    2720.0
    [m]
    DC
    LAP
    2724.0
    [m]
    SWC
    LAP
    2730.0
    [m]
    DC
    LAP
    2740.0
    [m]
    DC
    LAP
    2747.0
    [m]
    SWC
    LAP
    2750.0
    [m]
    DC
    LAP
    2760.0
    [m]
    DC
    LAP
    2770.0
    [m]
    DC
    LAP
    2780.0
    [m]
    DC
    LAP
    2782.1
    [m]
    SWC
    LAP
    2790.0
    [m]
    DC
    LAP
    2800.0
    [m]
    DC
    LAP
    2810.0
    [m]
    DC
    LAP
    2820.0
    [m]
    DC
    LAP
    2831.0
    [m]
    SWC
    LAP
    2840.0
    [m]
    DC
    LAP
    2860.0
    [m]
    DC
    LAP
    2880.0
    [m]
    DC
    LAP
    2900.0
    [m]
    DC
    LAP
    2905.0
    [m]
    DC
    LAP
    2907.5
    [m]
    SWC
    LAP
    2910.0
    [m]
    DC
    LAP
    2920.0
    [m]
    DC
    LAP
    2940.0
    [m]
    DC
    LAP
    2950.0
    [m]
    DC
    LAP
    2960.0
    [m]
    DC
    LAP
    2980.0
    [m]
    DC
    LAP
    2990.0
    [m]
    DC
    LAP
    3000.0
    [m]
    DC
    LAP
    3000.4
    [m]
    SWC
    LAP
    3010.0
    [m]
    DC
    LAP
    3020.0
    [m]
    DC
    LAP
    3030.0
    [m]
    DC
    LAP
    3040.0
    [m]
    DC
    LAP
    3050.0
    [m]
    DC
    LAP
    3060.0
    [m]
    DC
    LAP
    3070.0
    [m]
    DC
    LAP
    3080.0
    [m]
    DC
    LAP
    3083.0
    [m]
    SWC
    LAP
    3085.0
    [m]
    DC
    LAP
    3092.0
    [m]
    SWC
    LAP
    3100.0
    [m]
    DC
    LAP
    3105.0
    [m]
    DC
    LAP
    3115.0
    [m]
    DC
    LAP
    3120.0
    [m]
    DC
    LAP
    3140.0
    [m]
    DC
    LAP
    3160.0
    [m]
    DC
    LAP
    3167.0
    [m]
    SWC
    LAP
    3180.0
    [m]
    DC
    LAP
    3182.0
    [m]
    SWC
    LAP
    3200.0
    [m]
    DC
    LAP
    3220.0
    [m]
    DC
    LAP
    3240.0
    [m]
    DC
    LAP
    3260.0
    [m]
    DC
    LAP
    3280.0
    [m]
    DC
    LAP
    3300.0
    [m]
    DC
    LAP
    3320.0
    [m]
    DC
    LAP
    3335.0
    [m]
    SWC
    LAP
    3340.0
    [m]
    DC
    LAP
    3360.0
    [m]
    SWC
    LAP
    3360.0
    [m]
    DC
    LAP
    3380.0
    [m]
    DC
    LAP
    3391.0
    [m]
    SWC
    LAP
    3400.0
    [m]
    DC
    LAP
    3404.0
    [m]
    SWC
    LAP
    3420.0
    [m]
    DC
    LAP
    3430.5
    [m]
    SWC
    LAP
    3440.0
    [m]
    DC
    LAP
    3446.1
    [m]
    SWC
    LAP
    3460.0
    [m]
    DC
    LAP
    3480.0
    [m]
    DC
    LAP
    3481.9
    [m]
    SWC
    LAP
    3487.5
    [m]
    SWC
    LAP
    3500.0
    [m]
    DC
    LAP
    3500.2
    [m]
    SWC
    LAP
    3520.0
    [m]
    DC
    STRATL
    3520.0
    [m]
    DC
    LAP
    3520.5
    [m]
    SWC
    LAP
    3526.0
    [m]
    SWC
    LAP
    3530.0
    [m]
    DC
    STRATL
    3535.0
    [m]
    DC
    STRATL
    3538.5
    [m]
    SWC
    LAP
    3540.0
    [m]
    DC
    LAP
    3540.0
    [m]
    DC
    STRATL
    3546.0
    [m]
    SWC
    LAP
    3550.0
    [m]
    DC
    LAP
    3550.0
    [m]
    SWC
    LAP
    3550.0
    [m]
    DC
    STRATL
    3560.0
    [m]
    DC
    STRATL
    3560.0
    [m]
    DC
    LAP
    3560.5
    [m]
    SWC
    LAP
    3564.0
    [m]
    SWC
    LAP
    3570.0
    [m]
    DC
    STRATL
    3580.0
    [m]
    DC
    STRATL
    3580.0
    [m]
    DC
    LAP
    3590.0
    [m]
    DC
    STRATL
    3600.0
    [m]
    DC
    STRATL
    3600.0
    [m]
    DC
    LAP
    3610.0
    [m]
    DC
    STRATL
    3620.0
    [m]
    DC
    STRATL
    3620.0
    [m]
    DC
    LAP
    3630.0
    [m]
    DC
    STRATL
    3640.0
    [m]
    DC
    STRATL
    3640.0
    [m]
    DC
    LAP
    3650.0
    [m]
    DC
    LAP
    3650.0
    [m]
    DC
    STRATL
    3657.0
    [m]
    DC
    STRATL
    3660.0
    [m]
    DC
    LAP
    3661.0
    [m]
    DC
    LAP
    3661.1
    [m]
    C
    LAP
    3662.7
    [m]
    C
    RRI
    3665.9
    [m]
    C
    LAP
    3666.3
    [m]
    C
    LAP
    3668.5
    [m]
    C
    RRI
    3670.0
    [m]
    DC
    STRATL
    3675.3
    [m]
    C
    RRI
    3675.4
    [m]
    C
    LAP
    3680.0
    [m]
    DC
    LAP
    3680.0
    [m]
    C
    RRI
    3680.6
    [m]
    C
    STRATLAB
    3682.7
    [m]
    SWC
    OD
    3683.6
    [m]
    C
    LAP
    3686.2
    [m]
    C
    LAP
    3686.3
    [m]
    C
    LAP
    3690.0
    [m]
    DC
    STRATL
    3695.6
    [m]
    C
    OD
    3696.7
    [m]
    C
    LAP
    3699.3
    [m]
    C
    LAP
    3700.0
    [m]
    DC
    LAP
    3700.0
    [m]
    DC
    STRATL
    3704.5
    [m]
    SWC
    OD
    3710.0
    [m]
    DC
    STRATL
    3712.4
    [m]
    C
    LAP
    3717.0
    [m]
    DC
    STRATL
    3719.0
    [m]
    C
    RRI
    3719.1
    [m]
    C
    OD
    3720.0
    [m]
    DC
    LAP
    3722.0
    [m]
    DC
    STRATL
    3730.0
    [m]
    DC
    STRATL
    3735.0
    [m]
    DC
    RRI
    3740.0
    [m]
    DC
    LAP
    3740.0
    [m]
    DC
    STRATL
    3742.5
    [m]
    SWC
    RRI
    3747.5
    [m]
    SWC
    OD
    3750.0
    [m]
    DC
    STRATL
    3755.0
    [m]
    DC
    RRI
    3760.0
    [m]
    DC
    LAP
    3760.0
    [m]
    DC
    RRI
    3760.0
    [m]
    DC
    STRATL
    3767.5
    [m]
    SWC
    RRI
    3770.0
    [m]
    DC
    STRATL
    3770.0
    [m]
    DC
    RRI
    3777.5
    [m]
    SWC
    OD
    3780.0
    [m]
    DC
    STRATL
    3780.0
    [m]
    DC
    LAP
    3785.0
    [m]
    DC
    RRI
    3790.0
    [m]
    DC
    LAP
    3790.0
    [m]
    DC
    RRI
    3790.0
    [m]
    DC
    STRATL
    3799.5
    [m]
    DC
    LAP
    3800.0
    [m]
    DC
    LAP
    3800.0
    [m]
    DC
    STRATL
    3805.0
    [m]
    DC
    LAP
    3810.0
    [m]
    DC
    LAP
    3810.0
    [m]
    DC
    STRATL
    3815.0
    [m]
    DC
    LAP
    3820.0
    [m]
    DC
    LAP
    3820.0
    [m]
    DC
    STRATL
    3840.0
    [m]
    DC
    LAP
    3860.0
    [m]
    DC
    LAP
    3880.0
    [m]
    DC
    LAP
    3900.0
    [m]
    DC
    LAP
    3920.0
    [m]
    DC
    LAP
    3940.0
    [m]
    DC
    LAP
    3960.0
    [m]
    DC
    LAP
    3980.0
    [m]
    DC
    LAP
    3982.0
    [m]
    SWC
    LAP
    4000.0
    [m]
    DC
    LAP
    4020.0
    [m]
    DC
    LAP
    4035.0
    [m]
    SWC
    LAP
    4040.0
    [m]
    DC
    LAP
    4060.0
    [m]
    DC
    LAP
    4067.0
    [m]
    SWC
    LAP
    4080.0
    [m]
    DC
    LAP
    4102.0
    [m]
    DC
    LAP
    4115.0
    [m]
    SWC
    LAP
    4120.0
    [m]
    DC
    LAP
    4140.0
    [m]
    DC
    LAP
    4155.5
    [m]
    SWC
    LAP
    4160.0
    [m]
    DC
    LAP
    4180.0
    [m]
    DC
    LAP
    4194.0
    [m]
    SWC
    LAP
    4200.0
    [m]
    DC
    LAP
    4220.0
    [m]
    DC
    LAP
    4225.0
    [m]
    SWC
    LAP
    4240.0
    [m]
    DC
    LAP
    4260.0
    [m]
    DC
    LAP
    4280.0
    [m]
    DC
    LAP
    4295.0
    [m]
    SWC
    LAP
    4300.0
    [m]
    DC
    LAP
    4320.0
    [m]
    DC
    LAP
    4340.0
    [m]
    DC
    LAP
    4360.0
    [m]
    DC
    LAP
    4380.0
    [m]
    DC
    LAP
    4380.0
    [m]
    SWC
    LAP
    4400.0
    [m]
    DC
    LAP
    4420.0
    [m]
    DC
    LAP
    4420.0
    [m]
    SWC
    LAP
    4440.0
    [m]
    DC
    LAP
    4452.0
    [m]
    SWC
    LAP
    4460.0
    [m]
    DC
    LAP
    4470.0
    [m]
    DC
    LAP
    4480.0
    [m]
    DC
    LAP
    4484.0
    [m]
    DC
    LAP
    4490.0
    [m]
    DC
    LAP
    4500.0
    [m]
    DC
    LAP
    4510.0
    [m]
    DC
    LAP
    4510.0
    [m]
    SWC
    LAP
    4517.0
    [m]
    DC
    LAP
    4520.0
    [m]
    DC
    LAP
    4530.0
    [m]
    DC
    LAP
    4534.0
    [m]
    SWC
    LAP
    4535.0
    [m]
    DC
    LAP
    4540.0
    [m]
    DC
    LAP
    4547.0
    [m]
    SWC
    LAP
    4550.0
    [m]
    DC
    LAP
    4554.0
    [m]
    SWC
    LAP
    4555.0
    [m]
    DC
    LAP
    4556.0
    [m]
    SWC
    OD
    4560.0
    [m]
    DC
    LAP

  • 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
    3659.00
    3669.00
    06.05.1983 - 16:00
    YES

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.85

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    1.59
    pdf
    0.41
    pdf
    1.17
    pdf
    0.23
    pdf
    1.38
    pdf
    4.41
    pdf
    0.16
    pdf
    1.80
    pdf
    1.01

  • 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
    57.33
    pdf
    20.46
    pdf
    1.56
    pdf
    4.05
    pdf
    0.63
    pdf
    1.15
    pdf
    5.50
    pdf
    2.67
    pdf
    7.26
    pdf
    17.65
    pdf
    27.04
    pdf
    0.70
    pdf
    10.15
    pdf
    0.12
    pdf
    1.98
    pdf
    1.53
    pdf
    109.48
    pdf
    2.77
    pdf
    6.29
    pdf
    14.63
    pdf
    0.56
    pdf
    0.92
    pdf
    0.87
    pdf
    6.12
    pdf
    2.15
    pdf
    1.24
    pdf
    2.80
    pdf
    1.16
    pdf
    0.22
    pdf
    237.88

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    3659
    3669
    19.0
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    134
    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
    454
    394000
    0.792
    0.735
    869

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL VDL GR
    300
    1789
    CBL VDL GR
    1589
    3553
    CBL VDL GR
    3380
    3963
    CST
    1855
    2407
    CST
    2324
    3566
    CST
    2512
    3446
    CST
    3465
    3566
    CST
    3982
    4556
    DLL NGS
    3553
    3714
    DLWD
    2450
    3550
    GEODIP
    3654
    3805
    GEODIP
    3654
    3805
    GEODIP
    3795
    3963
    HDT
    3553
    3964
    HDT
    3970
    4558
    ISF LSS MSFL GR SP
    600
    3969
    ISF LSS MSFL GR SP NGT
    3970
    4556
    LDL CNL GR
    1816
    4558
    LDL GR
    660
    1816
    NGT
    3553
    3714
    RFT
    4102
    4556
    RFT GR
    3660
    3952
    SHDT
    3660
    3960
    WST VSP
    503
    4560

  • 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
    400.0
    36
    401.0
    0.00
    LOT
    SURF.COND.
    20
    901.0
    26
    901.0
    0.00
    LOT
    INTERM.
    13 3/8
    1789.0
    17 1/2
    1817.0
    1.88
    LOT
    INTERM.
    9 5/8
    3568.0
    12 1/4
    3568.0
    2.03
    LOT
    LINER
    7
    3969.0
    8 1/2
    3969.0
    1.88
    LOT
    OPEN HOLE
    4560.0
    7
    4560.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    520
    1.09
    31.0
    seawater
    1100
    1.14
    36.0
    waterbased
    1425
    1.14
    35.0
    waterbased
    1650
    1.22
    40.0
    waterbased
    1980
    1.40
    44.0
    waterbased
    2280
    1.66
    54.0
    waterbased
    3500
    1.71
    62.0
    waterbased
    3630
    1.25
    55.0
    waterbased
    4020
    1.18
    72.0
    waterbased
    4490
    1.30
    65.0
    waterbased

  • Pressure plots
    Pressure plots
    The pore pressure data is sourced from well logs if no other source is specified. In some wells where pore pressure logs do not exist, information from Drill stem tests and kicks have been used. The data has been reported to the NPD, and further processed and quality controlled by IHS Markit.
    Pressure plots
    Document name
    Document format
    Document size [MB]
    pdf
    0.28