Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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31.12.2024 - 01:26
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6407/8-6 A

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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.
    6407/8-6 A
    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
    Press release
    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.
    6407/8-6
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    3D survey ST 10021-inline 1344 & xline 2099
    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.
    Statoil Petroleum AS
    Drill permit
    The drilling permit number together with the version of the drilling permit as stated in the drilling permit granted by the Norwegian Offshore Directorate.
    1480-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.
    51
    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,
    20.10.2013
    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.
    09.12.2013
    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.
    09.12.2015
    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.
    09.12.2015
    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
    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.
    EARLY 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.
    TILJE 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.
    ILE FM
    3rd level with HC, age
    Age of lithostratigraphic unit, 3rd level, where hydrocarbons were encountered. Examples of legal values: CRETACEOUS, EARLY CRETACEOUS, LATE JURASSIC, EOCENE.
    MIDDLE JURASSIC
    3rd level with HC, formation
    Name of lithostartigraphic unit, 3rd level, where hydrocarbons were encountered. Shown only for released wells. Examples of legal values: BASEMENT, COOK FM, EKOFISK FM, HEIMDAL FM, SANDNES FM, SOGNEFJORD FM, TARBERT FM, BRENT GP.
    MELKE FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    25.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    282.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3537.0
    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).
    3288.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    43.5
    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.
    ÅRE FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    64° 21' 12.7'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    7° 27' 44.48'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7137484.98
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    425743.95
    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.
    7266

  • Wellbore history
    General
    Well 6407/8-6 A is a geological sidetrack to 6407/8-6. Both were drilled to test the Snilehorn Prospect on the Halten Terrace in the Norwegian Sea. The primary well had discovered oil in the Ile, Tilje, and Åre formations without seeing any oil/water contacts. The primary objective of 6407/8-6 A was to test the Jurassic sequence in a down-faulted segment east of the primary well bore.
    Operations and results
    Appraisal well 6407/8-6 A drilled with the semi-submersible installation Songa Trym. It was kicked off on 20 October 2013, immediately below the 9 5/8” shoe; the kick off point was confirmed at 1996 m. The sidetrack was drilled to 3537 m (3288 m TVD) in Late Triassic sediments belonging to the Åre Formation. Operations proceeded without significant problems. The well was drilled with XP-07 oil based mud from kick-off to TD.
    Top Garn Formation was penetrated at 2884 m (2722 m TVD), top Ile Formation at 3023 m (2824 m TVD), and top Tilje Formation at 3224 m (2985 m TVD). The Garn and Ile formations were oil bearing all through (down-to contacts), while the Tilje Formation was oil bearing with a true oil/water contact at 3284 m (3040 m TVD). Oil shows were described down to 3300 m. Based on logs and shows descriptions there was oil also in a 3 m sandstone in the Not Formation, from 2962 to 2965 m.
    Two cores were taken in the 6407/8-6 A well covering respectively 27 meters in the Garn and Not formations (2903 to 2930 m) and 13 meters in Ile Formation (3029 to 3041 m). No fluid samples were taken.
    The well was permanently abandoned on 9 December 2013 as an oil appraisal well.
    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]
    2000.00
    3537.00

  • 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
    2903.0
    2930.4
    [m ]
    2
    3029.0
    3040.9
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    39.2
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    2500.0
    [m]
    DC
    BIOSTRAT
    2510.0
    [m]
    DC
    BIOSTR
    2520.0
    [m]
    DC
    BIOSTR
    2530.0
    [m]
    DC
    BIOSTR
    2540.0
    [m]
    DC
    BIOSTR
    2550.0
    [m]
    DC
    BIOSTR
    2560.0
    [m]
    DC
    BIOSTR
    2570.0
    [m]
    DC
    BIOSTR
    2580.0
    [m]
    DC
    BIOSTR
    2590.0
    [m]
    DC
    BIOSTR
    2600.0
    [m]
    DC
    BIOSTR
    2610.0
    [m]
    DC
    BIOSTR
    2620.0
    [m]
    DC
    BIOSTR
    2630.0
    [m]
    DC
    BIOSTR
    2640.0
    [m]
    DC
    BIOSTR
    2650.0
    [m]
    DC
    BIOSTR
    2660.0
    [m]
    DC
    BIOSTR
    2670.0
    [m]
    DC
    BIOSTR
    2680.0
    [m]
    DC
    BIOSTR
    2690.0
    [m]
    DC
    BIOSTR
    2700.0
    [m]
    DC
    BIOSTR
    2709.0
    [m]
    DC
    BIOSTR
    2718.0
    [m]
    DC
    BIOSTR
    2727.0
    [m]
    DC
    BIOSTR
    2736.0
    [m]
    DC
    BIOSTR
    2745.0
    [m]
    DC
    BIOSTR
    2754.0
    [m]
    DC
    BIOSTR
    2763.0
    [m]
    DC
    BIOSTR
    2772.0
    [m]
    DC
    BIOSTR
    2781.0
    [m]
    DC
    BIOSTR
    2790.0
    [m]
    DC
    BIOSTR
    2799.0
    [m]
    DC
    BIOSTR
    2808.0
    [m]
    DC
    BIOSTR
    2817.0
    [m]
    DC
    BIOSTR
    2826.0
    [m]
    DC
    BIOSTR
    2835.0
    [m]
    DC
    BIOSTR
    2844.0
    [m]
    DC
    BIOSTR
    2853.0
    [m]
    DC
    BIOSTR
    2862.0
    [m]
    DC
    BIOSTR
    2871.0
    [m]
    DC
    BIOSTR
    2877.0
    [m]
    DC
    BIOSTR
    2883.0
    [m]
    DC
    BIOSTR
    2889.0
    [m]
    DC
    BIOSTR
    2895.0
    [m]
    DC
    BIOSTR
    2901.0
    [m]
    DC
    BIOSTR
    2903.2
    [m]
    C
    BIOSTR
    2907.0
    [m]
    DC
    BIOSTR
    2908.6
    [m]
    C
    BIOSTR
    2911.5
    [m]
    C
    BIOSTR
    2914.8
    [m]
    C
    BIOSTR
    2917.5
    [m]
    C
    BIOSTR
    2918.9
    [m]
    C
    BIOSTR
    2923.9
    [m]
    C
    BIOSTR
    2926.6
    [m]
    C
    BIOSTR
    2928.8
    [m]
    C
    BIOSTR
    2931.3
    [m]
    C
    BIOSTR
    2933.4
    [m]
    C
    BIOSTR
    2936.2
    [m]
    C
    BIOSTR
    2940.8
    [m]
    C
    BIOSTR
    2949.0
    [m]
    DC
    BIOSTR
    2958.0
    [m]
    DC
    BIOSTR
    2967.0
    [m]
    DC
    BIOSTR
    2979.0
    [m]
    DC
    BIOSTR
    2988.0
    [m]
    DC
    BIOSTR
    3003.0
    [m]
    DC
    BIOSTR
    3009.0
    [m]
    DC
    BIOSTR
    3021.0
    [m]
    DC
    BIOSTR
    3030.0
    [m]
    DC
    BIOSTR
    3036.0
    [m]
    DC
    BIOSTR
    3045.0
    [m]
    DC
    BIOSTR
    3054.0
    [m]
    DC
    BIOSTR
    3063.0
    [m]
    DC
    BIOSTR
    3072.0
    [m]
    DC
    BIOSTR
    3081.0
    [m]
    DC
    BIOSTR
    3090.0
    [m]
    DC
    BIOSTR
    3099.0
    [m]
    DC
    BIOSTR
    3108.0
    [m]
    DC
    BIOSTR
    3117.0
    [m]
    DC
    BIOSTR
    3126.0
    [m]
    DC
    BIOSTR
    3135.0
    [m]
    DC
    BIOSTR
    3144.0
    [m]
    DC
    BIOSTR
    3153.0
    [m]
    DC
    BIOSTR
    3162.0
    [m]
    DC
    BIOSTR
    3171.0
    [m]
    DC
    BIOSTR
    3180.0
    [m]
    DC
    BIOSTR
    3189.0
    [m]
    DC
    BIOSTR
    3198.0
    [m]
    DC
    BIOSTR
    3207.0
    [m]
    DC
    BIOSTR
    3216.0
    [m]
    DC
    BIOSTR
    3225.0
    [m]
    DC
    BIOSTR
    3234.0
    [m]
    DC
    BIOSTR
    3240.0
    [m]
    DC
    BIOSTR
    3252.0
    [m]
    DC
    BIOSTR
    3261.0
    [m]
    DC
    BIOSTR
    3270.0
    [m]
    DC
    BIOSTR
    3279.0
    [m]
    DC
    BIOSTR
    3288.0
    [m]
    DC
    BIOSTR
    3297.0
    [m]
    DC
    BIOSTR
    3306.0
    [m]
    DC
    BIOSTR
    3315.0
    [m]
    DC
    BIOSTR
    3324.0
    [m]
    DC
    BIOSTR
    3333.0
    [m]
    DC
    BIOSTR
    3342.0
    [m]
    DC
    BIOSTR
    3351.0
    [m]
    DC
    BIOSTR
    3360.0
    [m]
    DC
    BIOSTR
    3369.0
    [m]
    DC
    BIOSTR
    3378.0
    [m]
    DC
    BIOSTR
    3387.0
    [m]
    DC
    BIOSTR
    3396.0
    [m]
    DC
    BIOSTR
    3405.0
    [m]
    DC
    BIOSTR
    3414.0
    [m]
    DC
    BIOSTR
    3423.0
    [m]
    DC
    BIOSTR
    3432.0
    [m]
    DC
    BIOSTR
    3441.0
    [m]
    DC
    BIOSTR
    3450.0
    [m]
    DC
    BIOSTR
    3459.0
    [m]
    DC
    BIOSTR
    3468.0
    [m]
    DC
    BIOSTR
    3477.0
    [m]
    DC
    BIOSTR
    3486.0
    [m]
    DC
    BIOSTR
    3495.0
    [m]
    DC
    BIOSTR
    3504.0
    [m]
    DC
    BIOSTR
    3513.0
    [m]
    DC
    BIOSTR
    3522.0
    [m]
    DC
    BIOSTR
    3531.0
    [m]
    DC
    BIOSTR
    3537.0
    [m]
    DC
    BIOSTR

  • Lithostratigraphy

  • 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
    OPEN HOLE
    2000.0
    8 1/2
    3537.0
    0.00

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    1874
    1.42
    23.0
    XP-07 - Yellow
    1913
    1.41
    20.0
    XP-07 - Yellow
    3029
    1.41
    21.0
    XP-07 - Yellow
    3041
    1.41
    23.0
    XP-07 - Yellow
    3537
    1.42
    22.0
    XP-07 - Yellow
    3537
    1.41
    21.0
    XP-07 - Yellow