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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8/4-1

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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.
    8/4-1
    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
    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.
    8/4-1
    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.
    Unocal Norge A/S
    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.
    177-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.
    35
    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,
    21.06.1977
    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.
    25.07.1977
    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.
    25.07.1979
    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.
    22.04.2005
    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.
    24.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    63.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2632.0
    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).
    2631.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    4
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    90
    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.
    57° 44' 50.24'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    3° 0' 3.86'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6400720.56
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    500063.83
    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.
    302

  • Wellbore history
    General
    Wildcat well 8/4-1 is located in the Danish Norwegian Basin of the North Sea. The primary objective was to test the hydrocarbon potential of Middle Jurassic sandstones, expected at 2430 m with a 122 m thickness. A secondary objective was seen in the Late Cretaceous chalk. Planned TD was at 2850 m in the Permian Zechstein Group.
    Operations and results
    Wildcat well 8/4-1 was spudded with the semi-submersible installation Norjarl on 21 June 1977 and drilled to TD at 2632 m, 50 m into the Permian Zechstein Group. The well was drilled with lime and Drispac down to 1757 m and with, and lignosulphonate from 1757 m to TD.
    The well encountered a 116 m thick Middle Jurassic sandstones sequence (Bryne Formation) with top at 2397, fairly close to prognosis. The secondary target was also encountered close to prognosis, at 1664 m (Tor Formation). Early Cretaceous Cromer Knoll Group was found unconformable on Late Jurassic shales. The Upper part of the Boknfjord Group was not present in the well. The well was electrically logged from 85 m to 2623 m and no pay was present in the well to this depth. Trace residual oil shows were seen in sidewall cores at 2417 m and 2462 m. Total gas averaged 5 to 10 units throughout the course of drilling with no significant gas peaks. Shows of the heavier hydrocarbon gases C2 to C4 were present in the interval 2355 m to 2466 m. Three pressure regimes exists in this well. The first includes the Late Tertiary sediments and is only very slightly overpressured reaching approximately 9.2 ppg at its base at 899 m. This is the top of the second regime and marks the unconformity between the Late Tertiary and Eocene sediments. The Eocene and the Paleocene below, exhibit an increasing pore pressure with depth reaching a maximum of approximately 12.6 ppg EMW above the Paleocene/Late Cretaceous unconformity at 5261 ft. (1604 m). The third regime extends to TD and is assumed to be near normally pressured. Organic geochemical analyses indicated a thermally immature well all through with %Ro approaching 0.40 at TD. Good source rock, but immature at well site, was found in the Tau Formation, which had 3 - 7 % TOC and hydrogen index in the range 300 - 400 mg HC/g TOC. No conventional cores were cut. Twenty-seven sidewall cores were recovered out of 30 attempted. No fluid sample was taken.
    The well was permanently abandoned on 25 July as a dry hole.
    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]
    160.00
    2630.00

  • 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
    125.0
    36
    125.0
    0.00
    LOT
    SURF.COND.
    20
    410.0
    26
    433.0
    0.00
    LOT
    INTERM.
    13 3/8
    1378.0
    17 1/2
    1388.0
    0.00
    LOT
    OPEN HOLE
    2632.0
    12 1/4
    2632.0
    0.00
    LOT

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    BHC SONIC
    106
    433
    CALI
    43
    397
    CST
    1521
    2541
    FDC CNL GR
    1376
    2600
    FDC GR
    412
    1384
    GR
    85
    433
    HDT
    1376
    2602
    ISF SONIC GR
    412
    1385
    ISF SONIC GR
    1376
    2623
    TEMP
    86
    397
    TEMP
    100
    1350
    VELOCITY
    155
    2600
    WST
    155
    2600

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.44

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    3.17
    pdf
    1.57

  • 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
    3.45
    pdf
    2.24
    pdf
    46.70
    pdf
    0.70

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    159
    1.02
    seawater
    433
    1.09
    63.0
    seawater
    694
    1.07
    65.0
    seawater
    1388
    1.19
    47.0
    seawater
    1671
    1.27
    59.0
    seawater
    2437
    1.43
    50.0
    seawater
    2632
    1.49
    75.0
    seawater

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1000.0
    [m]
    DC
    RRI
    1020.0
    [m]
    DC
    RRI
    1060.0
    [m]
    DC
    RRI
    1090.0
    [m]
    DC
    RRI
    1120.0
    [m]
    DC
    RRI
    1140.0
    [m]
    DC
    RRI
    1150.0
    [m]
    DC
    RRI
    1170.0
    [m]
    DC
    RRI
    1180.0
    [m]
    DC
    RRI
    1200.0
    [m]
    DC
    RRI
    1210.0
    [m]
    DC
    RRI
    1230.0
    [m]
    DC
    RRI
    1240.0
    [m]
    DC
    RRI
    1260.0
    [m]
    DC
    RRI
    1270.0
    [m]
    DC
    RRI
    1290.0
    [m]
    DC
    RRI
    1300.0
    [m]
    DC
    RRI
    1320.0
    [m]
    DC
    RRI
    1330.0
    [m]
    DC
    RRI
    1350.0
    [m]
    DC
    RRI
    1360.0
    [m]
    DC
    RRI
    1380.0
    [m]
    DC
    RRI
    1390.0
    [m]
    DC
    RRI
    1405.0
    [m]
    DC
    RRI
    1410.0
    [m]
    DC
    RRI
    1420.0
    [m]
    DC
    RRI
    1430.0
    [m]
    DC
    RRI
    1435.0
    [m]
    DC
    RRI
    1440.0
    [m]
    DC
    RRI
    1450.0
    [m]
    DC
    RRI
    1455.0
    [m]
    DC
    RRI
    1465.0
    [m]
    DC
    RRI
    1470.0
    [m]
    DC
    RRI
    1480.0
    [m]
    DC
    RRI
    1485.0
    [m]
    DC
    RRI
    1495.0
    [m]
    DC
    RRI
    1510.0
    [m]
    DC
    RRI
    1515.0
    [m]
    DC
    RRI
    1520.0
    [m]
    DC
    RRI
    1530.0
    [m]
    DC
    RRI
    1535.0
    [m]
    DC
    RRI
    1540.0
    [m]
    DC
    RRI
    1550.0
    [m]
    DC
    RRI
    1555.0
    [m]
    DC
    RRI
    1560.0
    [m]
    DC
    RRI
    1565.0
    [m]
    DC
    RRI
    1570.0
    [m]
    DC
    RRI
    1575.0
    [m]
    DC
    RRI
    1580.0
    [m]
    DC
    RRI
    1585.0
    [m]
    DC
    RRI
    1595.0
    [m]
    DC
    RRI
    1600.0
    [m]
    DC
    RRI
    1605.0
    [m]
    DC
    RRI
    1610.0
    [m]
    DC
    RRI
    1620.0
    [m]
    DC
    RRI
    1635.0
    [m]
    DC
    RRI
    1650.0
    [m]
    DC
    RRI
    1665.0
    [m]
    DC
    RRI
    2352.0
    [m]
    DC
    PETROSTR
    2358.0
    [m]
    DC
    PETROS
    2382.0
    [m]
    DC
    PETROS
    2388.0
    [m]
    DC
    PETROS
    2403.0
    [m]
    DC
    PETROS
    2409.0
    [m]
    DC
    PETROS
    2414.0
    [m]
    DC
    PETROS
    3802.8
    [m]
    C
    PETROS
    3807.1
    [m]
    C
    PETROS
    3811.8
    [m]
    C
    PETROS