Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
27.12.2024 - 01:25
Time of last synchronization with Norwegian Offshore Directorate's internal systems

8/12-1

Export: PDF icon PDF

  • General information
    General information
    Attribute Value
    Wellbore name
    Official name of wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    8/12-1
    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.
    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.
    8/12-1
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    LINE C 8-6. SP.70
    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.
    Conoco 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.
    56-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.
    54
    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,
    31.05.1971
    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.
    23.07.1971
    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.
    23.07.1973
    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.
    24.09.2004
    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.
    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.
    34.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    62.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2875.0
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    82
    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.
    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.
    SKAGERRAK FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    57° 13' 18.6'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    3° 46' 45.13'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6342491.38
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    547054.64
    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.
    193

  • Wellbore history
    General
    Well 8/12-1 is located in the Åsta Graben. It was drilled on a salt dome with about 122 m of vertical closure over an area of about 23 km2. The well was programmed to test all porous formations from the Miocene to the Triassic. The main objectives were the Palaeocene Danian, Middle Jurassic, and Triassic sections. Secondary possibilities were seen in the Oligocene - Miocene, Late Cretaceous, and Early Cretaceous.
    The well is Reference Well for the Bryne Formation.
    Operations and results
    Wildcat well 8/12-1 was spudded with the jack-up installation Maersk Explorer on 31 May 1971 and drilled to TD at 2875m in the Skagerrak Formation. Some difficulties were encountered with over-pressured shales from 853 m to 1113 m before setting 13-3/8" casing, cementing the 13-3/8" casing, and with lost returns immediately below the 9-5/8" casing set at 1903 m. The well was drilled with a Seawater/gel/IMCO-RD-333 mud system with 3 % to 5 % oil.
    Methane gas in quantities up to 12% was recorded on the mud-gas detector during drilling of the Miocene and Oligocene clays. No significant reservoir sections were encountered in this section, and the gas was most probably released directly from the richly organic clays. Two very weak oil shows were obtained in the Middle Jurassic sandstones. In porous sandstones from core No.3, where one of these shows was observed, up to 9.4% residual oil was measured. However, evaluation of the logs showed that all porous intervals penetrated were water bearing. The formation water in the Middle Jurassic sandstones was calculated to have a salinity of 140,000 ppm NaCl.
    Three conventional cores were cut in the intervals 6181 feet - 6237 feet (1884.0 m - 1901.0 m), 8811 feet - 8817 feet (2685.6 m - 2687.4 m), and 8919 feet - 8969 feet (2718.5 m to 2733.8 m). One fluid sample was taken on wire line at 2666 m. The tool was opened for 10 min and recovered 100 cc of salt water (55,000 ppm NaCl).
    The well was permanently abandoned on 23 July 1971 as a dry hole with weak shows.
    Testing
    A DST was run over the interval 1902.6 m to 1950.7 m. Recovery in addition to the 457 m water cushion was 87 m of rat mud and 26 m of salt water cut mud. All pressure instruments indicated a low permeability zone that was depleted during the test period.

  • 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]
    106.68
    2871.22

  • 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
    6181.0
    6235.0
    [ft ]
    2
    8811.0
    8817.5
    [ft ]
    3
    8919.0
    8996.5
    [ft ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    42.1
    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
    8440.0
    [ft]
    DC
    PETROSTR
    8460.0
    [ft]
    DC
    PETROS
    8470.0
    [ft]
    DC
    PETROS
    8490.0
    [ft]
    DC
    PETROS
    8510.0
    [ft]
    DC
    PETROS
    8530.0
    [ft]
    DC
    PETROS
    8550.0
    [ft]
    DC
    PETROS
    8580.0
    [ft]
    DC
    PETROS
    8590.0
    [ft]
    DC
    PETROS
    8610.0
    [ft]
    DC
    PETROS
    8630.0
    [ft]
    DC
    PETROS
    8650.0
    [ft]
    DC
    PETROS
    8670.0
    [ft]
    DC
    PETROS
    8690.0
    [ft]
    DC
    PETROS
    8720.0
    [ft]
    DC
    PETROS
    8740.0
    [ft]
    DC
    PETROS
    8770.0
    [ft]
    DC
    PETROS
    8790.0
    [ft]
    DC
    PETROS
    8810.0
    [ft]
    DC
    PETROS
    8817.0
    [ft]
    C
    STRAT
    8830.0
    [ft]
    DC
    PETROS
    8850.0
    [ft]
    DC
    PETROS
    8870.0
    [ft]
    DC
    PETROS
    8890.0
    [ft]
    DC
    PETROS
    8919.0
    [ft]
    C
    STRAT
    8925.0
    [ft]
    C
    STRAT
    8928.0
    [ft]
    C
    STRAT
    8930.0
    [ft]
    C
    STRAT
    8940.0
    [ft]
    C
    STRAT
    8946.0
    [ft]
    C
    STRAT
    8952.0
    [ft]
    C
    STRAT
    8958.0
    [ft]
    C
    STRAT
    8964.0
    [ft]
    C
    STRAT
    8968.0
    [ft]
    C
    STRAT

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.33

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.98
    pdf
    0.86

  • 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
    20.51

  • Documents – Norwegian Offshore Directorate papers
    Documents – Norwegian Offshore Directorate papers
    Document name
    Document format
    Document size [MB]
    pdf
    33.18
    pdf
    0.64
    pdf
    0.49

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    BHC GR
    320
    2872
    FDC
    1601
    2874
    GR
    91
    320
    HDT
    1902
    2874
    IES
    333
    2874
    LL-7
    1902
    2872
    PROX ML
    762
    2872
    SNP
    1900
    2874

  • 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
    114.0
    36
    114.0
    0.00
    LOT
    SURF.COND.
    20
    333.0
    26
    347.0
    0.00
    LOT
    INTERM.
    13 3/8
    1070.0
    17 1/2
    1082.0
    0.00
    LOT
    INTERM.
    9 5/8
    1903.0
    12 1/4
    1911.0
    0.00
    LOT
    OPEN HOLE
    2875.0
    8 1/2
    2875.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    346
    1.07
    50.0
    seawater
    480
    1.61
    54.0
    seawater
    1082
    1.49
    53.0
    seawater
    1883
    1.65
    50.0
    seawater
    1950
    1.65
    54.0
    seawater
    2225
    1.65
    50.0
    seawater
    2645
    1.62
    49.0
    seawater
    2874
    1.62
    50.0
    seawater

  • Thin sections at the Norwegian Offshore Directorate
    Thin sections at the Norwegian Offshore Directorate
    Depth
    Unit
    6185.00
    [m ]
    6232.00
    [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
    0.22