Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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01.11.2024 - 01:26
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2/7-13

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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.
    2/7-13
    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.
    2/7-13
    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.
    Phillips Petroleum Company Norway
    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.
    210-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.
    80
    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,
    01.02.1979
    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.
    21.04.1979
    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.
    21.04.1981
    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.
    18.01.2007
    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.
    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.
    35.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    73.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3388.0
    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).
    3383.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    6.1
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    121
    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.
    EARLY CRETACEOUS
    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.
    SOLA FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    56° 29' 34.74'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    3° 1' 58.38'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6261089.22
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    502024.78
    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.
    272

  • Wellbore history
    General
    Exploration well 2/7-13 was drilled to the East of an intrusive salt dome in the Ekofisk area of the Norwegian sector of the North Sea. The structure had already been investigated by wells 1/9-4 and 1/9-5 to the west, and also above the salt dome in 2/7-12. The Danian/Late Cretaceous was the primary objective. A secondary objective was the possibility of a reservoir on the flank of the dome with the salt forming a seal.
    Operations and results
    Well 2/7-13 was spudded with the jack-up installation Dyvi Beta on 1 February 1979 and drilled to TD at 3388 m in the Early Cretaceous Sola Formation. No significant problems were reported from the operations. The well was drilled with spud mud/Drispac/seawater down to 1309 m, and with seawater/Drispac from 1309 m to TD.
    Higher hydrocarbon gasses were observed from 975 m to 1113 m. Very poor fluorescence was noted in the clay and occasional limestone in the same interval. Poor shows occurred in limestones at 2210 - 2225 m and 2265 - 2274 m, and also in dolomite limestone stringers from 2387 - 2591 m. The Danian and Cretaceous limestones also gave poor oil shows with some staining in the Ekofisk Formation from 2719 to 2801 m. Five conventional cores with a total of 22 m recovered were taken in this zone from 2725.5 m to 2790 m. No wire line fluid samples were taken.
    The well was permanently abandoned on 21 April 1979 as a dry well with shows.
    Testing
    Four intervals in the 8 1/2" section were tested through 7" liner. DST 1 tested the Hidra Formation from 3188 to 3257 m and produced 504 Sm3 water with 1.5% oil/day, DST 2 tested the Hod Formation from 3042 to 3085 m and produced 1441 Sm3 water with ca 3000 Sm3 gas/day, DST 3 tested the Ekofisk Formation from 2740 to 2774 m and 2793.5 to 2807 m, and DST 4 tested the Ekofisk Formation from 2697.5 to 2729 m. DST 3 and DST 4 produced only small amounts of water (1 Sm3/day and 69 Sm3/day, respectively). All rates were measured through a 38.1 mm choke.

  • 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]
    360.50
    3388.00

  • 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
    8942.0
    8948.0
    [ft ]
    2
    8973.0
    8985.0
    [ft ]
    3
    9104.0
    9118.0
    [ft ]
    4
    9118.0
    9124.6
    [ft ]
    5
    9138.0
    9154.0
    [ft ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    16.6
    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
    176.0
    36
    178.0
    0.00
    LOT
    SURF.COND.
    20
    346.0
    26
    361.0
    1.29
    LOT
    INTERM.
    13 3/8
    1502.0
    17 1/2
    1515.0
    1.54
    LOT
    INTERM.
    9 5/8
    2690.0
    12
    2722.0
    1.72
    LOT
    LINER
    7
    3382.0
    8 1/2
    3388.0
    0.00
    LOT

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    3188
    3205
    38.1
    2.0
    3042
    3084
    38.1
    3.0
    2794
    2807
    38.1
    4.0
    2697
    2729
    38.1
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    2.0
    3.0
    4.0
    Drill stem tests (DST)
    Test number
    Oil
    [Sm3/day]
    Gas
    [Sm3/day]
    Oil density
    [g/cm3]
    Gas grav. rel.air
    GOR
    [m3/m3]
    1.0
    2.0
    3.0
    4.0

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    DLL MSFL GR CAL
    2681
    3383
    FDC CNL GR
    2681
    3379
    FIL
    2690
    3392
    HDT
    2255
    3392
    ISF SONIC GR
    1498
    3382
    ISF SONIC GR SP
    292
    1512
    ISF SP
    1498
    2718
    VELOCITY
    344
    3382

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.34

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.70
    pdf
    0.20

  • Documents – reported by the production licence (period for duty of secrecy expired)

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    346
    1.03
    54.0
    waterbased
    657
    1.19
    39.0
    waterbased
    1309
    1.22
    44.0
    waterbased
    1739
    1.44
    41.0
    waterbased
    2365
    1.58
    48.0
    waterbased
    3152
    1.58
    47.0
    waterbased
    3388
    1.60
    53.0
    waterbased