Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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25.12.2024 - 01:26
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35/11-6

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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.
    35/11-6
    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.
    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.
    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.
    35/11-6
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    MN9003 - 302 & SP 632
    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.
    Mobil Exploration Norway INC
    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.
    714-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.
    82
    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,
    30.01.1992
    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.
    20.04.1992
    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.
    20.04.1994
    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.
    15.06.2005
    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.
    APPRAISAL
    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.
    OIL 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
    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.
    27.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    370.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3995.0
    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).
    3989.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    2.5
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    144
    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.
    EARLY 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.
    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° 11' 45.82'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    3° 27' 55.46'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6784876.16
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    525017.66
    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.
    1879

  • Wellbore history
    General
    Block 35/11 is located on the northwestern edge of the Horda Platform, on the Lomre and Uer Terrace. The Northern part of the Viking Graben is immediately to the Northwest. The block lies due north of the Troll Field. The well was drilled to appraise the 35/11-2 Discovery, which proved oil and gas in the Middle Jurassic and had shows in Late Jurassic Intra Heather Sandstones. The primary objective was to evaluate the Middle Jurassic sandstones of the Brent Group, and the location was chosen such that the OWC of the Tarbert Formation could be identified. The secondary objective was the Late Jurassic Intra Heather Sandstones, which were thought to be much thicker than in the 35/11-2 location.
    Operations and results
    Wildcat well 35/11-6 was spudded with the semi-submersible installation Sovereign Explorer on 30 January 1992 and drilled to TD at 3990 m in the Early Jurassic Statfjord Formation. The well was drilled with seawater and viscous pills to 985 m and with KCl/polymer mud from 985 m to TD. In the Late Jurassic, sandstones were found in the Upper Heather and Sognefjord Formations. In the Upper Heather Formation a very porous and permeable sandstone contained 1.2 m of oil. A core was taken at the base of this interval and an RFT sample at 3072.7 m recovered gas and heavy oil. RFT pressure and sampling data indicated that the zone had excellent permeability in places. The pressure data did not support communication with 35/11-2, and a large sampling pressure draw down indicated a limited accumulation. The sandstone in the Sognefjord Formation, although thicker, was much less porous and contained only traces of residual oil. Two cores were taken in this Formation and an RFT at 3174.5 m recovered only traces of hydrocarbons. In the Middle Jurassic Brent Group, shows were observed in cores but these were probably residual as petrophysical results showed only low oil saturations. The reservoir quality of the sandstones was generally poor and many of the RFT pretests taken were either dry or supercharged. An RFT sample at 3522.4 m contained mud filtrate and only traces of gas.
    No oil shows were recorded above top Jurassic and below base Brent Group. Organic geochemical analyses showed that both the Draupne and Heather Formations contained good to excellent source rocks for oil and gas generation. The top of the oil window is reached at about base Draupne Formation at 3000 m, peak-oil generation (0.8% Ro) at around 3250-3350 m, and the base of the oil window (1.0% Ro) at about 3700 m. The analyses showed that the Intra Heather RFT sample from 3072.7 m was a low-mature heavy oil (equivalent to a 0.7% Ro source rock), suggesting the live oil could have a rather local origin in either base Draupne or top Heather shales.
    Eleven cores were cut, recovering a total of 231 m of core. One was cut in the Upper Heather Formation, two in the Sognefjord Formation and eight in the Brent Group. Three RFT samples were taken, one at 3174.5 m in the Sognefjord Formation (mud filtrate with only trace of gas and light oil), one at 3072.7 m in the Intra Heather sandstone (water, gas and 37.7 deg.API oil), and one at 3522.4 m in the Tarbert Formation (mud filtrate with only trace of gas and oil).
    The well was permanently abandoned on 20 April 1992. The well contained a limited accumulation of live oil. It is classified as well with 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]
    990.00
    3989.00

  • 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
    3072.0
    3076.0
    [m ]
    2
    3162.0
    3180.7
    [m ]
    3
    3181.0
    3193.2
    [m ]
    4
    3501.0
    3513.0
    [m ]
    5
    3516.0
    3542.0
    [m ]
    6
    3544.0
    3558.0
    [m ]
    7
    3558.0
    3581.0
    [m ]
    8
    3581.0
    3608.8
    [m ]
    9
    3608.8
    3636.0
    [m ]
    10
    3636.5
    3673.0
    [m ]
    11
    3673.0
    3705.3
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    233.7
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 3072-3076m
    Core photo at depth: 3076-3077m
    Core photo at depth: 3162-3166m
    Core photo at depth: 3166-3170m
    Core photo at depth: 3170-3174m
    3072-3076m
    3076-3077m
    3162-3166m
    3166-3170m
    3170-3174m
    Core photo at depth: 3174-3178m
    Core photo at depth: 3178-3180m
    Core photo at depth: 3181-3185m
    Core photo at depth: 3185-3189m
    Core photo at depth: 3189-3193m
    3174-3178m
    3178-3180m
    3181-3185m
    3185-3189m
    3189-3193m
    Core photo at depth: 3193-3193m
    Core photo at depth: 3501-3506m
    Core photo at depth: 3506-3511m
    Core photo at depth: 3511-3513m
    Core photo at depth: 3516-3521m
    3193-3193m
    3501-3506m
    3506-3511m
    3511-3513m
    3516-3521m
    Core photo at depth: 3521-3526m
    Core photo at depth: 3526-3531m
    Core photo at depth: 3531-3536m
    Core photo at depth: 3536-3541m
    Core photo at depth: 3541-3542m
    3521-3526m
    3526-3531m
    3531-3536m
    3536-3541m
    3541-3542m
    Core photo at depth: 3544-3549m
    Core photo at depth: 3549-3554m
    Core photo at depth: 3554-3558m
    Core photo at depth: 3558-3563m
    Core photo at depth: 3563-3568m
    3544-3549m
    3549-3554m
    3554-3558m
    3558-3563m
    3563-3568m
    Core photo at depth: 3568-3573m
    Core photo at depth: 3573-3578m
    Core photo at depth: 3578-3581m
    Core photo at depth: 3581-3586m
    Core photo at depth: 3586-3591m
    3568-3573m
    3573-3578m
    3578-3581m
    3581-3586m
    3586-3591m
    Core photo at depth: 3591-3596m
    Core photo at depth: 3596-3601m
    Core photo at depth: 3601-3606m
    Core photo at depth: 3606-3608m
    Core photo at depth: 3608-3613m
    3591-3596m
    3596-3601m
    3601-3606m
    3606-3608m
    3608-3613m
    Core photo at depth: 3613-3618m
    Core photo at depth: 3618-3623m
    Core photo at depth: 3623-3628m
    Core photo at depth: 3628-3633m
    Core photo at depth: 3633-3636m
    3613-3618m
    3618-3623m
    3623-3628m
    3628-3633m
    3633-3636m
    Core photo at depth: 3636-3641m
    Core photo at depth: 3641-3646m
    Core photo at depth: 3646-3651m
    Core photo at depth: 3651-3656m
    Core photo at depth: 3656-3661m
    3636-3641m
    3641-3646m
    3646-3651m
    3651-3656m
    3656-3661m
    Core photo at depth: 3661-3666m
    Core photo at depth: 3666-3671m
    Core photo at depth: 3671-3673m
    Core photo at depth: 3673-3678m
    Core photo at depth: 3678-3683m
    3661-3666m
    3666-3671m
    3671-3673m
    3673-3678m
    3678-3683m
    Core photo at depth: 3683-3688m
    Core photo at depth: 3688-3693m
    Core photo at depth: 3693-3698m
    Core photo at depth: 3698-3703m
    Core photo at depth: 3704-3705m
    3683-3688m
    3688-3693m
    3693-3698m
    3698-3703m
    3704-3705m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    990.0
    [m]
    DC
    MOBIL
    1000.0
    [m]
    DC
    MOBIL
    1010.0
    [m]
    DC
    MOBIL
    1020.0
    [m]
    DC
    MOBIL
    1030.0
    [m]
    DC
    MOBIL
    1050.0
    [m]
    DC
    MOBIL
    1070.0
    [m]
    DC
    MOBIL
    1090.0
    [m]
    DC
    MOBIL
    1110.0
    [m]
    DC
    MOBIL
    1120.0
    [m]
    DC
    MOBIL
    1130.0
    [m]
    DC
    MOBIL
    1150.0
    [m]
    DC
    MOBIL
    1170.0
    [m]
    DC
    MOBIL
    1190.0
    [m]
    DC
    MOBIL
    1210.0
    [m]
    DC
    MOBIL
    1230.0
    [m]
    DC
    MOBIL
    1250.0
    [m]
    DC
    MOBIL
    1270.0
    [m]
    DC
    MOBIL
    1290.0
    [m]
    DC
    MOBIL
    1310.0
    [m]
    DC
    MOBIL
    1330.0
    [m]
    DC
    MOBIL
    1350.0
    [m]
    DC
    MOBIL
    1370.0
    [m]
    DC
    MOBIL
    1380.0
    [m]
    DC
    MOBIL
    1390.0
    [m]
    DC
    MOBIL
    1400.0
    [m]
    DC
    MOBIL
    1410.0
    [m]
    DC
    MOBIL
    1430.0
    [m]
    DC
    MOBIL
    1440.0
    [m]
    DC
    MOBIL
    1450.0
    [m]
    DC
    MOBIL
    1470.0
    [m]
    DC
    MOBIL
    1500.0
    [m]
    DC
    MOBIL
    1520.0
    [m]
    DC
    MOBIL
    1540.0
    [m]
    DC
    MOBIL
    1600.0
    [m]
    DC
    MOBIL
    1640.0
    [m]
    DC
    MOBIL
    1660.0
    [m]
    DC
    MOBIL
    1680.0
    [m]
    DC
    MOBIL
    1720.0
    [m]
    DC
    MOBIL
    1740.0
    [m]
    DC
    MOBIL
    1760.0
    [m]
    DC
    MOBIL
    1820.0
    [m]
    DC
    MOBIL
    1860.0
    [m]
    DC
    MOBIL
    1880.0
    [m]
    DC
    MOBIL
    1920.0
    [m]
    DC
    MOBIL
    2000.0
    [m]
    SWC
    MOBIL
    2029.0
    [m]
    SWC
    MOBIL
    2054.0
    [m]
    SWC
    MOBIL
    2077.0
    [m]
    SWC
    MOBIL
    2152.0
    [m]
    SWC
    MOBIL
    2180.0
    [m]
    SWC
    MOBIL
    2205.0
    [m]
    SWC
    MOBIL
    2227.0
    [m]
    SWC
    MOBIL
    2313.0
    [m]
    SWC
    MOBIL
    2360.0
    [m]
    DC
    RRI
    2405.0
    [m]
    SWC
    MOBIL
    2424.5
    [m]
    SWC
    MOBIL
    2451.5
    [m]
    SWC
    MOBIL
    2480.0
    [m]
    SWC
    MOBIL
    2532.5
    [m]
    SWC
    MOBIL
    2562.5
    [m]
    SWC
    MOBIL
    2580.0
    [m]
    DC
    RRI
    2603.0
    [m]
    DC
    RRI
    2623.5
    [m]
    SWC
    MOBIL
    2650.0
    [m]
    SWC
    MOBIL
    2669.0
    [m]
    DC
    RRI
    2676.0
    [m]
    SWC
    MOBIL
    2690.0
    [m]
    DC
    RRI
    2711.0
    [m]
    SWC
    MOBIL
    2720.0
    [m]
    DC
    RRI
    2733.0
    [m]
    SWC
    MOBIL
    2756.5
    [m]
    SWC
    MOBIL
    2768.0
    [m]
    SWC
    MOBIL
    2775.0
    [m]
    SWC
    MOBIL
    2802.0
    [m]
    SWC
    MOBIL
    2821.5
    [m]
    SWC
    MOBIL
    2840.0
    [m]
    SWC
    MOBIL
    2865.0
    [m]
    SWC
    MOBIL
    2876.0
    [m]
    DC
    RRI
    2891.0
    [m]
    SWC
    MOBIL
    2898.5
    [m]
    SWC
    MOBIL
    2905.0
    [m]
    SWC
    MOBIL
    2915.0
    [m]
    SWC
    MOBIL
    2924.0
    [m]
    DC
    MOBIL
    2938.5
    [m]
    SWC
    MOBIL
    2960.0
    [m]
    DC
    MOBIL
    2960.0
    [m]
    SWC
    MOBIL
    2986.0
    [m]
    SWC
    MOBIL
    2996.0
    [m]
    DC
    MOBIL
    3012.0
    [m]
    SWC
    MOBIL
    3026.0
    [m]
    DC
    MOBIL
    3032.0
    [m]
    DC
    MOBIL
    3038.5
    [m]
    SWC
    MOBIL
    3055.0
    [m]
    SWC
    MOBIL
    3059.0
    [m]
    DC
    MOBIL
    3062.5
    [m]
    SWC
    MOBIL
    3072.0
    [m]
    C
    MOBIL
    3073.0
    [m]
    C
    MOBIL
    3074.0
    [m]
    C
    MOBIL
    3076.0
    [m]
    C
    MOBIL
    3076.9
    [m]
    C
    MOBIL
    3080.0
    [m]
    DC
    MOBIL
    3093.0
    [m]
    SWC
    MOBIL
    3115.0
    [m]
    SWC
    MOBIL
    3116.0
    [m]
    DC
    MOBIL
    3133.0
    [m]
    SWC
    MOBIL
    3149.0
    [m]
    DC
    MOBIL
    3154.0
    [m]
    SWC
    MOBIL
    3164.0
    [m]
    C
    MOBIL
    3172.0
    [m]
    C
    MOBIL
    3178.0
    [m]
    C
    MOBIL
    3179.0
    [m]
    C
    MOBIL
    3179.8
    [m]
    C
    MOBIL
    3184.0
    [m]
    C
    MOBIL
    3186.0
    [m]
    C
    MOBIL
    3190.0
    [m]
    C
    MOBIL
    3191.9
    [m]
    C
    MOBIL
    3193.2
    [m]
    C
    MOBIL
    3202.0
    [m]
    SWC
    MOBIL
    3223.0
    [m]
    SWC
    MOBIL
    3247.5
    [m]
    SWC
    MOBIL
    3273.0
    [m]
    SWC
    MOBIL
    3295.0
    [m]
    SWC
    MOBIL
    3317.0
    [m]
    SWC
    RRI
    3340.0
    [m]
    SWC
    RRI
    3359.0
    [m]
    DC
    RRI
    3374.0
    [m]
    SWC
    RRI
    3401.0
    [m]
    DC
    RRI
    3418.0
    [m]
    SWC
    RRI
    3437.5
    [m]
    SWC
    RRI
    3445.5
    [m]
    SWC
    MOBIL
    3454.0
    [m]
    SWC
    RRI
    3476.0
    [m]
    DC
    RRI
    3494.0
    [m]
    SWC
    RRI
    3510.0
    [m]
    C
    RRI
    3517.5
    [m]
    C
    GEOSTRAT
    3520.9
    [m]
    C
    GEOSTR
    3525.5
    [m]
    C
    GEOSTR
    3529.0
    [m]
    C
    MOBIL
    3536.8
    [m]
    C
    GEOSTRAT
    3541.0
    [m]
    C
    MOBIL
    3541.8
    [m]
    C
    GEOSTRAT
    3545.0
    [m]
    C
    MOBIL
    3549.0
    [m]
    C
    MOBIL
    3551.6
    [m]
    C
    GEOSTRAT
    3559.3
    [m]
    C
    GEOSTR
    3560.0
    [m]
    C
    MOBIL
    3568.4
    [m]
    C
    GEOSTRAT
    3569.0
    [m]
    C
    MOBIL
    3574.0
    [m]
    C
    MOBIL
    3574.3
    [m]
    C
    GEOSTRAT
    3581.0
    [m]
    C
    MOBIL
    3582.5
    [m]
    C
    GEOSTRAT
    3588.6
    [m]
    C
    GEOSTR
    3589.5
    [m]
    C
    MOBIL
    3595.6
    [m]
    C
    GEOSTRAT
    3600.7
    [m]
    C
    GEOSTR
    3601.0
    [m]
    C
    MOBIL
    3622.5
    [m]
    C
    GEOSTRAT
    3644.9
    [m]
    C
    GEOSTR
    3649.4
    [m]
    C
    GEOSTR
    3651.0
    [m]
    C
    RRI
    3660.0
    [m]
    C
    RRI
    3667.3
    [m]
    C
    GEOSTRAT
    3673.5
    [m]
    C
    GEOSTR
    3680.0
    [m]
    C
    RRI
    3689.0
    [m]
    C
    RRI
    3702.0
    [m]
    C
    RRI
    3723.0
    [m]
    SWC
    RRI
    3731.5
    [m]
    SWC
    RRI
    3765.5
    [m]
    SWC
    RRI
    3772.2
    [m]
    SWC
    RRI
    3788.5
    [m]
    SWC
    RRI
    3809.0
    [m]
    DC
    RRI
    3830.0
    [m]
    DC
    RRI
    3851.0
    [m]
    DC
    RRI
    3884.0
    [m]
    DC
    RRI
    3956.0
    [m]
    SWC
    RRI

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.47

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    5.99

  • Documents – reported by the production licence (period for duty of secrecy expired)
    Documents – reported by the production licence (period for duty of secrecy expired)
    Document name
    Document format
    Document size [MB]
    pdf
    3.28
    pdf
    67.66

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CST GR
    2000
    3295
    CST GR
    3317
    3956
    CST GR
    3395
    3940
    DIT LSS GR AMS
    3138
    3987
    DIT SDT AMS GR
    1988
    3306
    DIT SDT LDT GR AMS
    979
    1995
    DLL MSFL VDL AMS GR
    2695
    3303
    LDT CNT AMS GR
    1988
    3307
    LDT CNT MSFL AMS NGT
    3298
    3987
    MOBIL LSAL SWAL GR
    945
    1990
    MOBIL LSAL SWAL GR
    1988
    3292
    MOBIL LSAL SWAL GR
    3298
    3987
    MWD - GR RES DIR
    396
    3990
    RFT HP GR P S
    2737
    3188
    RFT HP GR P S
    3072
    3192
    RFT HP GR P S
    3518
    3855
    SHDT GR
    2064
    3307
    SHDT GR
    3298
    3987
    VSP
    400
    3980

  • 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
    455.0
    36
    462.0
    0.00
    LOT
    INTERM.
    20
    979.0
    26
    985.0
    1.58
    LOT
    INTERM.
    13 3/8
    1988.0
    17 1/2
    1996.0
    1.63
    LOT
    INTERM.
    9 5/8
    3296.0
    12 1/4
    3310.0
    1.86
    LOT
    OPEN HOLE
    3995.0
    8 1/2
    3995.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    462
    1.07
    WATER BASED
    985
    1.07
    WATER BASED
    1273
    1.20
    17.0
    WATER BASED
    1541
    1.20
    17.0
    WATER BASED
    1740
    1.28
    17.0
    WATER BASED
    1996
    1.28
    26.0
    WATER BASED
    2078
    1.18
    23.0
    WATER BASED
    2117
    1.18
    22.0
    WATER BASED
    2135
    1.18
    19.0
    WATER BASED
    2173
    1.18
    21.0
    WATER BASED
    2344
    1.20
    22.0
    WATER BASED
    2576
    1.23
    23.0
    WATER BASED
    2770
    1.20
    20.0
    WATER BASED
    3031
    1.22
    16.0
    WATER BASED
    3072
    1.24
    14.0
    WATER BASED
    3080
    1.24
    14.0
    WATER BASED
    3129
    1.24
    17.0
    WATER BASED
    3162
    1.24
    16.0
    WATER BASED
    3180
    1.24
    11.0
    WATER BASED
    3194
    1.26
    15.0
    WATER BASED
    3206
    1.26
    14.0
    WATER BASED
    3304
    1.26
    19.0
    WATER BASED
    3475
    1.52
    19.0
    WATER BASED
    3645
    1.51
    27.0
    WATER BASED
    3672
    1.51
    27.0
    WATER BASED
    3704
    1.51
    27.0
    WATER BASED
    3800
    1.50
    24.0
    WATER BASED
    3877
    1.50
    24.0
    WATER BASED
    3990
    1.49
    24.0
    WATER BASED

  • Thin sections at the Norwegian Offshore Directorate
    Thin sections at the Norwegian Offshore Directorate
    Depth
    Unit
    3175.03
    [m ]
    3163.48
    [m ]
    3184.49
    [m ]

  • 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
    0.23