Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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22.12.2024 - 01:25
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8/10-6 S

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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.
    8/10-6 S
    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
    Press release
    Multilateral
    Indicator telling if the parent well is multilateral, meaning it has more than one branch radiating from the main borehole. Example of legal values: YES, NO. See also Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    NO
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    Main area
    Name of the area on the Norwegian Continental Shelf where the wellbore is located. Legal values: BARENTS SEA, NORWEGIAN SEA, NORTH SEA.
    NORTH SEA
    Well name
    Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    8/10-6
    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.
    Centrica Resources (Norge) 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.
    1524-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.
    49
    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,
    29.05.2014
    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.
    16.07.2014
    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.
    16.07.2016
    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.
    16.07.2016
    Purpose - planned
    Pre-drill purpose of the wellbore. Legal values for exploration wellbores: WILDCAT, APPRAISAL, WILDCAT-CCS, APPRAISAL-CCS. Example of legal values for development wellbores: OBSERVATION, PRODUCTION, INJECTION.
    WILDCAT
    Content
    For exploration wellbores, status of discovery.

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

    For development wellbores, type of produced/injected fluid.
    Legal values:
    WATER, CUTTINGS, NOT AVAILABLE, OIL, GAS/CONDENSATE, OIL/GAS, CO2, GAS, WATER/GAS, NOT APPLICABLE.
    DRY
    Discovery wellbore
    Indicator which tells if the wellbore made a new discovery. Legal values: YES, NO. Prior to press-release or other information regarding drilling results, the indicator will be “NO” as a default.
    NO
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    44.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    66.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2256.0
    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).
    1945.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    50
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    98
    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.
    PERMIAN
    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.
    ZECHSTEIN GP
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    57° 3' 9.92'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    3° 3' 42.12'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6323401.91
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    503743.02
    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.
    7485

  • Wellbore history
    General
    Well 8/10-6 S was drilled on the Butch SW prospect, a salt-induced structure on the Sørvestlandet high, approximately 13 km SE of the Ula Field in the North Sea. The Butch structure has three potentially separate prospects, divided by radial faulting from the salt diapir. The north-west prospect (Butch) was tested by well 8/10-4 S and sidetracks 8/10-4 A&B and found oil in Ula Formation sandstones. The eastern compartment (Butch East) was tested by 8/10-5 S and sidetrack 8/10-5 A and was dry. The primary objective of drilling 8/10-6 S was to test the hydrocarbon potential in the Ula Formation in the Butch south-west compartment. A secondary objective was to penetrate the underlying Zechstein salts to establish a seismic tie.
    Operations and results
    Wildcat well 8/10-6 S was spudded with the jack-up installation Mærsk Giant on 29 May 2014 and drilled to TD at 2256 m (1945 m TVD) m, 60 m into the Permian Zechstein Group. The well was drilled deviated in order to avoid significant shallow gas warnings and to allow the borehole to intersect the target Ula Formation at angle close to perpendicular. A 12 1/4" pilot hole was drilled to a planned depth of 703 m to check for shallow gas. This was deepened to 722 m after observing elevated concentrations heavier alkanes in drilled gas, over the interval 657 m to 702 m. otherwise no shallow gas was seen. Some hole problems were experienced in the 17 1/2" section where volumes of large tabular cavings were produced. The cavings originated from the uppermost part of the Hordaland Group. This correspond to the same problem interval in 8/10-4 B, which was abandoned after excessive cavings production and hole collapse. The well was drilled with Spud mud down to 180 m, with Glydril mud from 180 m to 703 m, with Versatec oil based mud from 703 m to 1995 m, and with Warp oil based mud from 1995 m to TD.
    The target Ula Formation was found to be water wet, and potential reservoir properties in the Farsund Formation were not developed. No oil shows above the oil based mud was described in the well. Chromatograph ratios detected elevated amounts of heavier hydrocarbons over the interval 811 to 1090 m in the basal Nordland Group and upper Hordaland Group.
    One conventional core was cut through the Ula Formation from 2057.0 to 2111.0 m with 99% recovery. No fluid sample was taken. Wireline and circulation temperatures at TD were rather high in this well compared to the other Butch wells, corresponding to a gradient close to 50 °C/km.
    The well was permanently abandoned on 16 July 2014 as a dry 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]
    190.00
    2255.00

  • 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
    2057.0
    2110.5
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    53.5
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Casing and leak–off tests
    Casing and leak–off tests
    Casing type
    Casing diam.
    [inch]
    Casing depth
    [m]
    Hole diam.
    [inch]
    Hole depth
    [m]
    LOT/FIT mud eqv.
    [g/cm3]
    Formation test type
    CONDUCTOR
    30
    179.7
    36
    179.7
    0.00
    SURF.COND.
    20
    719.0
    26
    722.0
    1.77
    LOT
    INTERM.
    13 3/8
    1482.0
    17 1/2
    1486.0
    1.86
    LOT
    LINER
    9 5/8
    1994.0
    12 1/4
    1995.0
    1.87
    LOT
    OPEN HOLE
    2256.0
    8 1/2
    2256.0
    0.00

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    GYRO
    139
    1442
    LWD - GABI GR RES PWD DIR
    1989
    2057
    LWD - GABI GR RES SON DEN CALI N
    1479
    1986
    LWD - GR PWD DEN SON RES NEU FPT
    1985
    2251
    LWD - GR RES SON PWD DIR
    722
    1418
    LWD - PWD DIR
    170
    716
    LWD - PWD RES GR DIR SON
    170
    716
    PPC SS IS PPC GR LEH
    1
    2257
    USIT CBL
    487
    1417
    VSI-4
    665
    2250

  • Lithostratigraphy

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    1486
    1.65
    64.0
    Versatec
    1650
    1.65
    55.0
    Versatec
    1973
    1.67
    52.0
    Versatec
    1995
    1.67
    51.0
    Versatec
    2057
    1.68
    29.0
    Warp
    2111
    1.67
    29.0
    Warp
    2256
    1.67
    44.0
    Versatec

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1970.0
    [m]
    DC
    PETROSTR
    1980.0
    [m]
    DC
    PETROS
    1990.0
    [m]
    DC
    PETROS
    1995.0
    [m]
    DC
    PETROS
    2001.0
    [m]
    DC
    PETROS
    2007.0
    [m]
    DC
    PETROS
    2013.0
    [m]
    DC
    PETROS
    2019.0
    [m]
    DC
    PETROS
    2025.0
    [m]
    DC
    PETROS
    2031.0
    [m]
    DC
    PETROS
    2037.0
    [m]
    DC
    PETROS
    2043.0
    [m]
    DC
    PETROS
    2049.0
    [m]
    DC
    PETROS
    2055.0
    [m]
    DC
    PETROS
    2057.0
    [m]
    DC
    PETROS
    2067.0
    [m]
    DC
    PETROS
    2077.0
    [m]
    DC
    PETROS
    2087.0
    [m]
    DC
    PETROS
    2097.0
    [m]
    DC
    PETROS
    2107.0
    [m]
    DC
    PETROS
    2112.0
    [m]
    DC
    PETROS