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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7120/8-4

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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.
    7120/8-4
    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
    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.
    BARENTS SEA
    Well name
    Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    7120/8-4
    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.
    StatoilHydro ASA
    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.
    1140-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.
    27
    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,
    14.11.2007
    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.
    10.12.2007
    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.
    10.12.2009
    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.
    10.12.2009
    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.
    23.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    275.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2697.0
    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).
    2696.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    4.2
    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.
    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.
    FRUHOLMEN FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    71° 28' 36.76'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    20° 26' 44.22'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7930889.05
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    480342.17
    UTM zone
    Universal Transverse Mercator zone. Examples of legal values: 31, 32, 33, 34.
    34
    NPDID wellbore
    Norwegian Offshore Directorate's unique id for the wellbore.
    5572

  • Wellbore history
    Well 7120/8-4 was drilled on the Askeladd Beta prospect in block 7120/8 about 6 kilometres south-west of the Snøhvit field and 150 kilometres north-west of Hammerfest. The purpose of the well was to prove hydrocarbons in Jurassic sandstones as additional resources for a potential expansion of the LNG plant on Melkøya.
    Operations and results
    A 9 7/8" pilot hole (7120/8-U-4) was first drilled to 500 m to detect possible shallow gas in a zone at 370 m. No shallow gas was detected. Wildcat well 7120/8-4 was spudded with the semi-submersible installation Polar Pioneer on 14 November 2007 and drilled to TD at 2697 m in the Late Triassic Fruholmen Formation. Boulders were encountered in the 36" top hole section. No significant problems were encountered during the operations. The well was drilled with spud mud/high viscosity sweeps and returns to seafloor down to 1246 m and with Formpro WBM from 1246 m to TD.
    Top Stø and Tubåen Formations were penetrated at 2263.8 and 2495.7 m respectively. The well was dry, with only traces of hydrocarbons. However, in the Stø and Fruholmen Formations significant background gas and residual oil from the interpretation shows that this structure might have been hydrocarbon filled formerly. The presence of kerogens in the Stø Formation gave a general spotty direct HC fluorescence and a weak cut reaction (with 2-iso-proponol) in zones rich in siltstones or in some of the zones packed with kaolinittic matrix/cement. One particular stringer of calcareous sandstone, at 2325 ? 2332 m, gave a particular good HC-fluorescence as well as the cut reaction. The appearance of fluorescence was generally absent below 2523 m.
    No cores were cut and no wire line fluid samples were taken.
    The well was permanently abandoned on 10 December 2007 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]
    1260.00
    2697.00

  • 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
    346.0
    36
    351.0
    1.65
    LOT
    INTERM.
    13 3/8
    1244.0
    17 1/2
    1252.0
    2.05
    LOT
    INTERM.
    9 5/8
    2249.0
    12 1/4
    2250.0
    0.00
    LOT
    OPEN HOLE
    2697.0
    8 1/2
    2697.0
    0.00
    LOT

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    MDT PRETEST
    2265
    2678
    MWD - ARCVRES8-POWERPULSE
    351
    1252
    MWD - GVR6-ARCVRES6 POWERPULSE
    2250
    2697
    MWD - GVR8 ARCVRES8 POWERPULSE
    1252
    2250
    MWD - POWERPULSE
    275
    351
    PEX HNGS MSIP
    1250
    2697
    VSP
    347
    2680

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.30

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    1528
    1.26
    15.0
    FORMPRO
    1949
    1.26
    15.0
    FORMPRO
    2250
    1.30
    16.0
    FORMPRO
    2262
    1.30
    20.0
    FORMPRO

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1260.0
    [m]
    DC
    APT
    1280.0
    [m]
    DC
    APT
    1300.0
    [m]
    DC
    APT
    1320.0
    [m]
    DC
    APT
    1340.0
    [m]
    DC
    APT
    1360.0
    [m]
    DC
    APT
    1380.0
    [m]
    DC
    APT
    1400.0
    [m]
    DC
    APT
    1420.0
    [m]
    DC
    APT
    1440.0
    [m]
    DC
    APT
    1460.0
    [m]
    DC
    APT
    1480.0
    [m]
    DC
    APT
    1500.0
    [m]
    DC
    APT
    1520.0
    [m]
    DC
    APT
    1540.0
    [m]
    DC
    APT
    1560.0
    [m]
    DC
    APT
    1580.0
    [m]
    DC
    APT
    1600.0
    [m]
    DC
    APT
    1620.0
    [m]
    DC
    APT
    1640.0
    [m]
    DC
    APT
    1660.0
    [m]
    DC
    APT
    1680.0
    [m]
    DC
    APT
    1700.0
    [m]
    DC
    APT
    1720.0
    [m]
    DC
    APT
    1740.0
    [m]
    DC
    APT
    1760.0
    [m]
    DC
    APT
    1780.0
    [m]
    DC
    APT
    1800.0
    [m]
    DC
    APT
    1820.0
    [m]
    DC
    APT
    1840.0
    [m]
    DC
    APT
    1860.0
    [m]
    DC
    APT
    1880.0
    [m]
    DC
    APT
    1900.0
    [m]
    DC
    APT
    1920.0
    [m]
    DC
    APT
    1940.0
    [m]
    DC
    APT
    1960.0
    [m]
    DC
    APT
    1980.0
    [m]
    DC
    APT
    2000.0
    [m]
    DC
    APT
    2020.0
    [m]
    DC
    APT
    2040.0
    [m]
    DC
    APT
    2060.0
    [m]
    DC
    APT
    2080.0
    [m]
    DC
    APT
    2100.0
    [m]
    DC
    APT
    2110.0
    [m]
    DC
    APT
    2120.0
    [m]
    DC
    APT
    2130.0
    [m]
    DC
    APT
    2140.0
    [m]
    DC
    APT
    2150.0
    [m]
    DC
    APT
    2160.0
    [m]
    DC
    APT
    2170.0
    [m]
    DC
    APT
    2180.0
    [m]
    DC
    APT
    2190.0
    [m]
    DC
    APT
    2200.0
    [m]
    DC
    APT
    2210.0
    [m]
    DC
    APT
    2220.0
    [m]
    DC
    APT
    2230.0
    [m]
    DC
    APT
    2240.0
    [m]
    DC
    APT
    2250.0
    [m]
    DC
    APT
    2256.0
    [m]
    DC
    APT
    2262.0
    [m]
    DC
    APT
    2268.0
    [m]
    DC
    APT
    2274.0
    [m]
    DC
    APT
    2280.0
    [m]
    DC
    APT
    2286.0
    [m]
    DC
    APT
    2292.0
    [m]
    DC
    APT
    2298.0
    [m]
    DC
    APT
    2304.0
    [m]
    DC
    APT
    2310.0
    [m]
    DC
    APT
    2316.0
    [m]
    DC
    APT
    2322.0
    [m]
    DC
    APT
    2328.0
    [m]
    DC
    APT
    2334.0
    [m]
    DC
    APT
    2340.0
    [m]
    DC
    APT
    2346.0
    [m]
    DC
    APT
    2352.0
    [m]
    DC
    APT
    2358.0
    [m]
    DC
    APT
    2364.0
    [m]
    DC
    APT
    2370.0
    [m]
    DC
    APT
    2376.0
    [m]
    DC
    APT
    2382.0
    [m]
    DC
    APT
    2394.0
    [m]
    DC
    APT
    2412.0
    [m]
    DC
    APT
    2418.0
    [m]
    DC
    APT
    2430.0
    [m]
    DC
    APT
    2436.0
    [m]
    DC
    APT
    2454.0
    [m]
    DC
    APT
    2460.0
    [m]
    DC
    APT
    2466.0
    [m]
    DC
    APT
    2472.0
    [m]
    DC
    APT
    2478.0
    [m]
    DC
    APT
    2484.0
    [m]
    DC
    APT
    2490.0
    [m]
    DC
    APT
    2496.0
    [m]
    DC
    APT
    2502.0
    [m]
    DC
    APT
    2508.0
    [m]
    DC
    APT
    2514.0
    [m]
    DC
    APT
    2526.0
    [m]
    DC
    APT
    2532.0
    [m]
    DC
    APT
    2538.0
    [m]
    DC
    APT
    2544.0
    [m]
    DC
    APT
    2550.0
    [m]
    DC
    APT
    2556.0
    [m]
    DC
    APT
    2562.0
    [m]
    DC
    APT
    2574.0
    [m]
    DC
    APT
    2586.0
    [m]
    DC
    APT
    2592.0
    [m]
    DC
    APT
    2598.0
    [m]
    DC
    APT
    2610.0
    [m]
    DC
    APT
    2622.0
    [m]
    DC
    APT
    2628.0
    [m]
    DC
    APT
    2640.0
    [m]
    DC
    APT
    2652.0
    [m]
    DC
    APT
    2658.0
    [m]
    DC
    APT
    2664.0
    [m]
    DC
    APT
    2670.0
    [m]
    DC
    APT
    2676.0
    [m]
    DC
    APT
    2682.0
    [m]
    DC
    APT
    2688.0
    [m]
    DC
    APT
    2697.0
    [m]
    DC
    APT