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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2/8-7

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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.
    2/8-7
    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
    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.
    2/8-7
    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.
    134-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.
    33
    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,
    23.07.1975
    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.
    24.08.1975
    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.
    24.08.1977
    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
    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
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    33.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    68.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2868.0
    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).
    2868.0
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    113
    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 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.
    56° 26' 49.8'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    3° 36' 50.6'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6256157.92
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    537855.51
    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.
    277

  • Wellbore history
    General
    Well 2/8-7 is located on the western side of the Piggvar Terrace towards the Feda Graben. The well was drilled to test the Late Cretaceous Limestone in the Trud structure. Structurally, the Trud anomaly is a high relief, salt induced, domal feature covering approximately 19 square kilometres. The structure was seen as highly faulted with a main fault trending north south, with the down-thrown side to the east. The displacement along this fault was estimated to approximately 150 m. No secondary objective was defined.
    Operations and results
    Wildcat well 2/8-7 was spudded with the jack-up installation Zapata Explorer on 23 July 1975 and drilled to a total depth of 2868 m in the Late Permian salt. The well was drilled without major problems. The well was drilled with seawater gel down to 375 m, and with a Lime/Drispac/seawater mud system from 375 m to TD. The mud weight was cut and LCM pills spotted at 2619 m to cure lost circulation problems.
    The Tertiary section consisted predominantly of claystone and shale. The Paleocene ash markerá (Balder Formation) was encountered at 2511 m and was found to be 12 m thick. The Shetland Group chalk section (Ekofisk, Tor, and Hod Formations) was encountered at 2596 m. The Chalk section had a vertical thickness of 223 m, which compares to roughly 451 m in 2/5-4, 458 m in 2/9-1 and 280 m in 2/8-2. Oil shows were recorded in limestone stringers below 1548 m. The target Late Crataceous section had 12 m of oil shows from top of the Danian chalk (Ekofisk Formation), the core from this section was boiling gas and bleeding oil from vugs and fractures. Schlumberger logs were run before the 9 5/8-inch casing was set and after total depth was reached. Coriband log analysis estimated a water saturation around 60% in the top Ekofisk section. A core was cut from 8538 to 8554 feet (ca 2602 m to 2607 m) with 50% recovery. No fluid samples were taken. The well was permanently abandoned on 24 August as a well with oil 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]
    152.40
    2846.83

  • 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
    8538.0
    8546.0
    [ft ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    2.4
    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
    146.0
    36
    146.0
    0.00
    LOT
    SURF.COND.
    20
    371.0
    26
    375.0
    0.00
    LOT
    INTERM.
    13 3/8
    1298.0
    17 1/2
    1303.0
    0.00
    LOT
    INTERM.
    9 5/8
    2576.0
    12 1/4
    2576.0
    0.00
    LOT
    OPEN HOLE
    2868.0
    8 1/2
    2868.0
    0.00
    LOT

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL
    485
    1368
    DIP
    2579
    2867
    DLL MSFL SP GR CAL
    1295
    2565
    DLL MSFL SP GR CAL
    2575
    2867
    FDC CNL GR CAL
    1296
    2575
    FDC CNL GR CAL
    2575
    2867
    GR SONIC CAL
    1297
    2575
    GR SONIC CAL
    2575
    2867
    IES SP
    2575
    2867
    VELOCITY
    304
    2867

  • Lithostratigraphy
    Lithostratigraphy
    Top depth [mMD RKB]
    Lithostrat. unit
    101
    1360
    2511
    2511
    2521
    2538
    2582
    2596
    2596
    2627
    2739
    2819
    2825

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.39

  • 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
    9.06

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    374
    1.05
    65.0
    seawater
    653
    1.25
    45.0
    seawater
    1285
    1.28
    51.0
    seawater
    1323
    1.79
    65.0
    seawater
    2345
    1.80
    55.0
    seawater

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    7420.0
    [ft]
    DC
    HRS
    7480.0
    [ft]
    DC
    HRS
    7540.0
    [ft]
    DC
    HRS
    7590.0
    [ft]
    DC
    HRS
    7620.0
    [ft]
    DC
    HRS
    7650.0
    [ft]
    DC
    HRS
    7720.0
    [ft]
    DC
    HRS
    7780.0
    [ft]
    DC
    HRS
    7860.0
    [ft]
    DC
    HRS
    7920.0
    [ft]
    DC
    HRS
    7980.0
    [ft]
    DC
    HRS
    8040.0
    [ft]
    DC
    HRS
    8100.0
    [ft]
    DC
    HRS
    8160.0
    [ft]
    DC
    HRS
    8210.0
    [ft]
    DC
    HRS
    8270.0
    [ft]
    DC
    HRS
    8330.0
    [ft]
    DC
    HRS
    8390.0
    [ft]
    DC
    HRS
    8410.0
    [ft]
    DC
    HRS
    8430.0
    [ft]
    DC
    HRS
    8450.0
    [ft]
    DC
    HRS
    8470.0
    [ft]
    DC
    HRS
    8490.0
    [ft]
    DC
    HRS
    8510.0
    [ft]
    DC
    HRS
    8530.0
    [ft]
    DC
    HRS
    8550.0
    [ft]
    DC
    HRS
    8600.0
    [ft]
    DC
    HRS