Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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26.12.2024 - 01:26
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6507/5-1

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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.
    6507/5-1
    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
    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.
    6507/5-1
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    INLINE 274 SP 1170 - 1180
    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.
    Amoco Norway Oil Company
    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.
    919-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.
    131
    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,
    24.12.1997
    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.
    03.05.1998
    Plugged date
    Date when plugging operations was finished, as reported by the operator to the Norwegian Offshore Directorate through DDRS (Daily Drilling Reporting System).
    03.05.1998
    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.
    13.10.2019
    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.
    03.05.2000
    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.
    15.11.2001
    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.
    OIL/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.
    LATE CRETACEOUS
    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.
    LANGE 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.
    FANGST GP
    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.
    EARLY 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.
    BÅT GP
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    23.3
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    323.2
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4224.0
    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).
    4222.0
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    147
    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.
    ÅRE FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    65° 44' 36.11'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    7° 39' 4.6'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7292152.72
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    438172.23
    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.
    3683

  • Wellbore history
    General
    The purpose of the 6507/5-1 well was to test the Jurassic sandstones of the Donnatello prospect and potential Cretaceous sandstones. The prospect is located between the Norne and Heidrun fields, in the area of the Dønna Terrace in Nordland II, and about 200km off the coast of Helgeland in North Norway. The well was drilled to allow for future re-entry and re-completion as a producer.
    Operations and results
    Well 6507/5-1 was drilled with the semisubmersible rig Maersk Jutlander. Water based mud was used down to 1065, oil based mud from there to TD. The well was spudded on December 24th 1997, and TD was reached March 7th 1998. The well reached a TD of 4224 m MD in the Early Jurassic Åre formation. Gas condensate and oil were discovered in Jurassic sandstones of the Fangst and Båt groups, as well as additional oil discovered in sandstones of the Cretaceous Lange Formation. Six cores were cut in the Garn, Not, Ile, and Ror Formations from 3392.5 to 3542.7 m RKB. Another three cores were cut in the Ror, Tofte, Tilje, and Åre Formations from 3562 to 3698.6 m. Thirteen MDT samples containing variable proportions of gas, oil, and mud filtrate were taken in the Lange, Garn, Ile, and Tilje Formations while four MDT samples containing water were taken in the Åre Formation. Following the discovery, Donnatello was renamed Skarv and the well was suspended as an oil and gas discovery.
    Testing
    Before testing the well was cleaned and displaced to a Calcium Chloride brine. Three separate cased hole drill stem tests were run. Two tests were conducted in the Jurassic and one in the Cretaceous Lange formation. DST1 in the Jurassic Tilje formation produced 628 m3 oil with 109,804 m3 of gas per day through a 15.87mm choke. DST2a in the Jurassic Garn formation produced 178m3 of oil with 741,460 m3 of gas per day through a 15.87mm choke. DST2b from the Jurassic Garn and Ile formations combined produced 148m3 of oil and 580,560m3 of gas per day through a 12.70mm choke. DST3 in the Cretaceous Lange formation produced 925m3 of oil and 222,155m3 of gas per day through a 14.28mm choke.

  • 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]
    1080.00
    4223.00

  • 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
    3392.5
    3392.7
    [m ]
    2
    3395.0
    3422.1
    [m ]
    3
    3422.1
    3449.8
    [m ]
    4
    3449.8
    3470.9
    [m ]
    5
    3470.9
    3498.4
    [m ]
    6
    3498.4
    3542.7
    [m ]
    7
    3562.0
    3613.5
    [m ]
    8
    3616.0
    3645.6
    [m ]
    9
    3645.0
    3698.6
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    282.6
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 3392-3393m
    Core photo at depth: 3395-3400m
    Core photo at depth: 3400-3405m
    Core photo at depth: 3405-3410m
    Core photo at depth: 3410-3415m
    3392-3393m
    3395-3400m
    3400-3405m
    3405-3410m
    3410-3415m
    Core photo at depth: 3415-3420m
    Core photo at depth: 3420-3422m
    Core photo at depth: 3422-3427m
    Core photo at depth: 3427-3432m
    Core photo at depth: 3432-3437m
    3415-3420m
    3420-3422m
    3422-3427m
    3427-3432m
    3432-3437m
    Core photo at depth: 3437-3442m
    Core photo at depth: 3442-3447m
    Core photo at depth: 3447-3449m
    Core photo at depth: 3449-3454m
    Core photo at depth: 3454-3459m
    3437-3442m
    3442-3447m
    3447-3449m
    3449-3454m
    3454-3459m
    Core photo at depth: 3459-3464m
    Core photo at depth: 3464-3469m
    Core photo at depth: 3469-3470m
    Core photo at depth: 3470-3475m
    Core photo at depth: 3475-3480m
    3459-3464m
    3464-3469m
    3469-3470m
    3470-3475m
    3475-3480m
    Core photo at depth: 3480-3485m
    Core photo at depth: 3485-3490m
    Core photo at depth: 3490-3495m
    Core photo at depth: 3495-3498m
    Core photo at depth: 3498-3503m
    3480-3485m
    3485-3490m
    3490-3495m
    3495-3498m
    3498-3503m
    Core photo at depth: 3503-3508m
    Core photo at depth: 3508-3513m
    Core photo at depth: 3513-3518m
    Core photo at depth: 3518-3523m
    Core photo at depth: 3523-3528m
    3503-3508m
    3508-3513m
    3513-3518m
    3518-3523m
    3523-3528m
    Core photo at depth: 3528-3533m
    Core photo at depth: 3533-3538m
    Core photo at depth: 3538-3542m
    Core photo at depth: 3562-3567m
    Core photo at depth: 3567-3572m
    3528-3533m
    3533-3538m
    3538-3542m
    3562-3567m
    3567-3572m
    Core photo at depth: 3572-3577m
    Core photo at depth: 3577-3582m
    Core photo at depth: 3582-3587m
    Core photo at depth: 3587-3592m
    Core photo at depth: 3592-3597m
    3572-3577m
    3577-3582m
    3582-3587m
    3587-3592m
    3592-3597m
    Core photo at depth: 3597-3602m
    Core photo at depth: 3602-3607m
    Core photo at depth: 3607-3612m
    Core photo at depth: 3612-3613m
    Core photo at depth: 3616-3621m
    3597-3602m
    3602-3607m
    3607-3612m
    3612-3613m
    3616-3621m
    Core photo at depth: 3621-3626m
    Core photo at depth: 3626-3631m
    Core photo at depth: 3631-3636m
    Core photo at depth: 3636-3641m
    Core photo at depth: 3641-3645m
    3621-3626m
    3626-3631m
    3631-3636m
    3636-3641m
    3641-3645m
    Core photo at depth: 3645-3650m
    Core photo at depth: 3650-3655m
    Core photo at depth: 3655-3660m
    Core photo at depth: 3660-3665m
    Core photo at depth: 3665-3670m
    3645-3650m
    3650-3655m
    3655-3660m
    3660-3665m
    3665-3670m
    Core photo at depth: 3670-3675m
    Core photo at depth: 3675-3680m
    Core photo at depth: 3680-3685m
    Core photo at depth: 3685-3690m
    Core photo at depth: 3690-3695m
    3670-3675m
    3675-3680m
    3680-3685m
    3685-3690m
    3690-3695m
    Core photo at depth: 3695-3698m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    3695-3698m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1440.0
    [m]
    DC
    RRI
    1500.0
    [m]
    DC
    RRI
    1560.0
    [m]
    DC
    RRI
    1560.0
    [m]
    SWC
    RRI
    1590.0
    [m]
    DC
    RRI
    1620.0
    [m]
    DC
    RRI
    1650.0
    [m]
    DC
    RRI
    1680.0
    [m]
    DC
    RRI
    1710.0
    [m]
    DC
    RRI
    1740.0
    [m]
    DC
    RRI
    1770.0
    [m]
    DC
    RRI
    1800.0
    [m]
    DC
    RRI
    1820.0
    [m]
    DC
    RRI
    1830.0
    [m]
    DC
    RRI
    1860.0
    [m]
    DC
    RRI
    1880.0
    [m]
    DC
    RRI
    1900.0
    [m]
    DC
    RRI
    1920.0
    [m]
    DC
    RRI
    1939.0
    [m]
    DC
    RRI
    1966.0
    [m]
    DC
    RRI
    1987.0
    [m]
    DC
    RRI
    2002.0
    [m]
    DC
    RRI
    2020.0
    [m]
    DC
    RRI
    2032.0
    [m]
    DC
    RRI
    2050.0
    [m]
    DC
    RRI
    2062.0
    [m]
    DC
    RRI
    2068.0
    [m]
    DC
    RRI
    2076.0
    [m]
    DC
    RRI
    2086.0
    [m]
    DC
    RRI
    2101.0
    [m]
    DC
    RRI
    2125.0
    [m]
    DC
    RRI
    2137.0
    [m]
    DC
    RRI
    2149.0
    [m]
    DC
    RRI
    2167.0
    [m]
    DC
    RRI
    2182.0
    [m]
    DC
    RRI
    2194.0
    [m]
    DC
    RRI
    2209.0
    [m]
    DC
    RRI
    2233.0
    [m]
    DC
    RRI
    2257.0
    [m]
    DC
    RRI
    2266.0
    [m]
    DC
    RRI
    2281.0
    [m]
    DC
    RRI
    2299.0
    [m]
    DC
    RRI
    2311.0
    [m]
    DC
    RRI
    2326.0
    [m]
    DC
    RRI
    2344.0
    [m]
    DC
    RRI
    2359.0
    [m]
    DC
    RRI
    2374.0
    [m]
    DC
    RRI
    2380.0
    [m]
    DC
    RRI
    2404.0
    [m]
    DC
    RRI
    2416.0
    [m]
    DC
    RRI
    2434.0
    [m]
    DC
    RRI
    2446.0
    [m]
    DC
    RRI
    2464.0
    [m]
    DC
    RRI
    2476.0
    [m]
    DC
    RRI
    2497.0
    [m]
    DC
    RRI
    2509.0
    [m]
    DC
    RRI
    2527.0
    [m]
    DC
    RRI
    2539.0
    [m]
    DC
    RRI
    2557.0
    [m]
    DC
    RRI
    2569.0
    [m]
    DC
    RRI
    2587.0
    [m]
    DC
    RRI
    2599.0
    [m]
    DC
    RRI
    2614.0
    [m]
    DC
    RRI
    2626.0
    [m]
    DC
    RRI
    2644.0
    [m]
    DC
    RRI
    2659.0
    [m]
    DC
    RRI
    2674.0
    [m]
    DC
    RRI
    2689.0
    [m]
    DC
    RRI
    2704.0
    [m]
    DC
    RRI
    2715.8
    [m]
    SWC
    RRI
    2725.0
    [m]
    DC
    RRI
    2734.0
    [m]
    DC
    RRI
    2749.0
    [m]
    DC
    RRI
    2769.0
    [m]
    SWC
    RRI
    2779.0
    [m]
    DC
    RRI
    2794.0
    [m]
    DC
    RRI
    2809.0
    [m]
    DC
    RRI
    2824.4
    [m]
    SWC
    RRI
    2839.0
    [m]
    DC
    RRI
    2854.0
    [m]
    DC
    RRI
    2865.0
    [m]
    SWC
    RRI
    2890.0
    [m]
    SWC
    RRI
    2899.0
    [m]
    DC
    RRI
    2914.0
    [m]
    DC
    RRI
    2929.0
    [m]
    DC
    RRI
    2949.0
    [m]
    SWC
    RRI
    2964.0
    [m]
    SWC
    RRI
    2974.0
    [m]
    DC
    RRI
    2992.5
    [m]
    SWC
    RRI
    3005.0
    [m]
    SWC
    RRI
    3021.5
    [m]
    SWC
    RRI
    3030.5
    [m]
    SWC
    RRI
    3044.0
    [m]
    SWC
    RRI
    3064.0
    [m]
    DC
    RRI
    3079.0
    [m]
    DC
    RRI
    3088.0
    [m]
    DC
    RRI
    3094.0
    [m]
    DC
    RRI
    3103.0
    [m]
    DC
    RRI
    3109.0
    [m]
    DC
    RRI
    3118.0
    [m]
    DC
    RRI
    3123.0
    [m]
    SWC
    RRI
    3146.5
    [m]
    SWC
    RRI
    3154.0
    [m]
    DC
    RRI
    3174.5
    [m]
    SWC
    RRI
    3192.0
    [m]
    SWC
    RRI
    3196.0
    [m]
    SWC
    RRI
    3198.5
    [m]
    SWC
    RRI
    3214.0
    [m]
    DC
    RRI
    3229.0
    [m]
    DC
    RRI
    3245.0
    [m]
    DC
    RRI
    3251.0
    [m]
    C
    RRI
    3268.0
    [m]
    C
    RRI
    3288.0
    [m]
    C
    RRI
    3300.0
    [m]
    C
    RRI
    3327.5
    [m]
    C
    RRI
    3338.0
    [m]
    C
    RRI
    3352.0
    [m]
    C
    RRI
    3360.0
    [m]
    C
    RRI
    3362.0
    [m]
    DC
    RRI
    3365.0
    [m]
    C
    RRI
    3368.0
    [m]
    DC
    RRI
    3370.0
    [m]
    C
    RRI
    3375.0
    [m]
    C
    RRI
    3384.0
    [m]
    DC
    RRI
    3392.0
    [m]
    DC
    RRI
    3395.7
    [m]
    C
    RRI
    3402.5
    [m]
    C
    RRI
    3417.8
    [m]
    C
    RRI
    3431.6
    [m]
    C
    RRI
    3433.1
    [m]
    C
    RRI
    3448.3
    [m]
    C
    RRI
    3456.3
    [m]
    C
    RRI
    3460.0
    [m]
    C
    RRI
    3465.0
    [m]
    C
    RRI
    3470.9
    [m]
    C
    RRI
    3473.0
    [m]
    C
    RRI
    3474.4
    [m]
    C
    RRI
    3477.0
    [m]
    C
    RRI
    3480.6
    [m]
    C
    RRI
    3482.9
    [m]
    C
    RRI
    3490.0
    [m]
    C
    RRI
    3500.3
    [m]
    C
    RRI
    3507.6
    [m]
    C
    RRI
    3515.1
    [m]
    C
    RRI
    3521.0
    [m]
    C
    RRI
    3523.4
    [m]
    C
    RRI
    3542.6
    [m]
    C
    RRI
    3567.5
    [m]
    C
    RRI
    3574.4
    [m]
    C
    RRI
    3575.2
    [m]
    C
    RRI
    3579.5
    [m]
    C
    RRI
    3585.1
    [m]
    C
    RRI
    3595.1
    [m]
    C
    RRI
    3601.7
    [m]
    C
    RRI
    3608.4
    [m]
    C
    RRI
    3617.9
    [m]
    C
    RRI
    3623.5
    [m]
    C
    RRI
    3633.6
    [m]
    C
    RRI
    3642.8
    [m]
    C
    RRI
    3647.8
    [m]
    C
    RRI
    3653.1
    [m]
    C
    RRI
    3655.6
    [m]
    C
    RRI
    3657.4
    [m]
    C
    RRI
    3673.7
    [m]
    C
    RRI
    3682.7
    [m]
    C
    RRI
    3690.8
    [m]
    C
    RRI
    3696.9
    [m]
    C
    RRI
    3707.0
    [m]
    DC
    RRI
    3716.0
    [m]
    DC
    RRI
    3724.0
    [m]
    C
    RRI
    3734.0
    [m]
    DC
    RRI
    3743.0
    [m]
    DC
    RRI
    3752.0
    [m]
    DC
    RRI
    3761.0
    [m]
    DC
    RRI
    3767.0
    [m]
    DC
    RRI
    3779.0
    [m]
    DC
    RRI
    3788.0
    [m]
    DC
    RRI
    3797.0
    [m]
    DC
    RRI
    3815.0
    [m]
    DC
    RRI
    3824.0
    [m]
    DC
    RRI
    3833.0
    [m]
    DC
    RRI
    3842.0
    [m]
    DC
    RRI
    3851.0
    [m]
    DC
    RRI
    3857.0
    [m]
    DC
    RRI
    3941.0
    [m]
    DC
    RRI
    3989.0
    [m]
    DC
    RRI
    3998.0
    [m]
    DC
    RRI
    4142.0
    [m]
    DC
    RRI
    4151.0
    [m]
    DC
    RRI
    4160.0
    [m]
    DC
    RRI
    4169.0
    [m]
    DC
    RRI
    4178.0
    [m]
    DC
    RRI
    4187.0
    [m]
    DC
    RRI
    4196.0
    [m]
    DC
    RRI

  • 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
    DST1
    3607.00
    3653.00
    OIL
    02.04.1998 - 07:35
    YES
    DST
    DST2
    3430.00
    3442.00
    CONDENSATE
    13.04.1998 - 18:00
    YES
    DST
    DST2A
    3494.00
    3514.00
    CONDENSATE
    15.04.1998 - 21:30
    YES
    DST
    DST3
    2993.00
    3001.00
    OIL
    26.04.1998 - 08:53
    YES

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.69

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    1.88
    pdf
    1.68

  • 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
    79.48

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    3607
    3653
    15.9
    2.1
    3430
    3442
    15.9
    2.2
    3430
    3514
    12.7
    3.0
    2993
    3001
    14.3
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    8.000
    37.000
    2.1
    19.000
    36.000
    2.2
    22.000
    3.0
    18.000
    42.000
    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
    628
    109000
    0.857
    0.700
    175
    2.1
    178
    741000
    0.759
    0.670
    4164
    2.2
    148
    580000
    0.767
    0.675
    3926
    3.0
    925
    222000
    0.829
    0.670
    240

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    AIT DSI GR
    1053
    3221
    AIT DSI GR
    3200
    4220
    CMR
    2770
    3120
    CMR2000
    3350
    3800
    IPLT
    1053
    3223
    IPLT
    3200
    4225
    MDT
    1382
    3091
    MDT
    3381
    3873
    MDT
    3406
    3770
    MDT
    3582
    4182
    MSCT
    1382
    3199
    MSCT
    2715
    3031
    MSCT
    3251
    4132
    MWD CDR GR RES
    350
    485
    MWD CDR GR RES
    496
    1063
    MWD CDR GR RES
    3239
    4224
    MWD DIR
    442
    496
    MWD RAB GR RES
    1069
    3236
    OBDT
    2804
    3192
    UBI
    3095
    3187
    UBI
    3126
    3210
    UBI
    3228
    4210
    USIT
    2890
    3085
    USIT
    3100
    3700
    W VSP
    1800
    2300
    ZO VSP
    1580
    2180
    ZO VSP
    2180
    4130

  • 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
    480.0
    36
    496.0
    0.00
    LOT
    SURF.COND.
    20
    1053.0
    26
    1065.0
    1.67
    LOT
    INTERM.
    9 5/8
    3199.0
    12 1/4
    3236.0
    1.95
    LOT
    LINER
    7
    3863.0
    8 1/2
    4224.0
    0.00
    LOT
    OPEN HOLE
    4224.0
    8 1/2
    4224.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    350
    1.60
    kill mud
    350
    1.20
    spud mud
    442
    1.60
    kill mud
    442
    1.00
    spud mud
    496
    1.60
    kill mud
    496
    1.00
    spud mud
    571
    1.00
    spud mud
    571
    1.50
    kill mud
    1053
    1.50
    kill mud
    1053
    1.00
    spud mud
    1065
    1.50
    kill mud
    1065
    1.30
    spud mud
    1065
    1.00
    sea water
    1065
    1.40
    oil based
    3199
    1.40
    oil based
    3235
    1.40
    oil based
    3236
    1.50
    oil based
    3241
    1.40
    oil based
    3472
    1.40
    oil based
    3542
    1.40
    oil based
    3932
    1.40
    oil based
    4085
    1.46
    oil based
    4224
    1.46
    oil based

  • 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