Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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04.11.2024 - 01:25
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2/7-4

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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.
    2/7-4
    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
    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
    Field
    Name of the field the wellbore is related to.
    Discovery
    Name of the discovery the wellbore is related to.
    Well name
    Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    2/7-4
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    Line PS 5628 & SP 82
    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.
    71-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.
    73
    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,
    23.06.1972
    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.
    03.09.1972
    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.
    03.09.1974
    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
    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.
    OIL
    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.
    YES
    1st level with HC, age
    Age of lithostratigraphic unit, 1st level, where hydrocarbons were encountered. Examples of legal values: CRETACEOUS, EARLY CRETACEOUS, LATE JURASSIC, EOCENE. See also Norwegian Offshore Directorate bulletins.
    PALEOCENE
    1st level with HC, formation
    Name of lithostartigraphic unit, 1st level, where hydrocarbons were encountered. Shown only for released wells. Examples of legal values: BASEMENT, COOK FM, EKOFISK FM, HEIMDAL FM, SANDNES FM, SOGNEFJORD FM, TARBERT FM, BRENT GP. See also Norwegian Offshore Directorate bulletins.
    EKOFISK FM
    2nd level with HC, age
    Age of lithostratigraphic unit, 2nd level, where hydrocarbons were encountered. Examples of legal values: CRETACEOUS, EARLY CRETACEOUS, LATE JURASSIC, EOCENE.
    LATE CRETACEOUS
    2nd level with HC, formation
    Name of lithostartigraphic unit, 2nd level, where hydrocarbons were encountered. Shown only for released wells. Examples of legal values: BASEMENT, COOK FM, EKOFISK FM, HEIMDAL FM, SANDNES FM, SOGNEFJORD FM, TARBERT FM, BRENT GP.
    TOR FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    26.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    72.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3356.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    1.6
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    110
    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 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.
    TOR FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    56° 27' 52.03'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    3° 6' 12'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6257917.77
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    506367.48
    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.
    263

  • Wellbore history
    General
    Well 2/7-4 is located in the southern part of the Norwegian North Sea and ca 10 km south east of the Ekofisk Field. The primary objective was the Danian Chalk, expected to be 90 m thick and possibly completely hydrocarbon bearing.
    Secondary objective was Late Cretaceous carbonates, especially in the upper part, which could be oil bearing in communication with the Danian. Planned TD was at 3353 m in the Late Cretaceous. In the event that hydrocarbon shows were still evident at the proposed TD the well would be deepened until potential productive zones were completely penetrated.
    Operations and results
    Wildcat well 2/7-4 was spudded with the semi-submersible installation Ocean Viking on 23 June 1972 and drilled to TD at 3356 m in the Late Cretaceous Tor Formation. The well was drilled without significant problems.
    The "Danian Chalk" (Ekofisk Formation) was encountered at 3096 m, and the Late Cretaceous Tor Formation at 3186 m. Both formations were oil bearing. DST's and logs indicate oil down to 3225 m, while the deepest test at 3291 - 3266 m produced water, some gas, and trace oil. Oil shows were recorded on cores in the interval 3133 m to 3246 m.
    Twelve cores were cut from 3116 m to 3264 in the Ekofisk and Tor Formations. No wire line fluid samples taken.
    The well was permanently abandoned on 3 September 1972 on as an oil discovery.
    Testing
    Six DST's were conducted in the Ekofisk and Tor Formations. Maximum production data after acid treatment follows: DST 1 tested the interval 3292 - 3266 m in the Tor Formation and produced 67 m3/day water, 2800 Sm3/day gas, and trace oil. DST 2 tested the interval 3197 - 3234 m in the Tor Formation and produced 1054 Sm3 oil and 273600 Sm3 gas /day on a 44/64" choke. The GOR was 260 Sm3/Sm3 and the oil gravity was 37.7 deg API. DST 3 tested the interval 3149 - 3170 m in the Ekofisk Formation and produced 200 Sm3 oil and 71200 Sm3 gas /day on a 36/64" choke. The GOR was 357 Sm3/Sm3 and the oil gravity was 44.5 deg API. DST 4 from the interval 3127 m to 3145 m in the Ekofisk Formation produced only water cushion: no formation fluid came to surface. DST 5 and DST 6 tested the interval 3106 m to 3114 m in the Upper Ekofisk Formation and produced small quantities of oil and gas to the surface from a nearly tight formation.

  • 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]
    487.68
    3352.80

  • 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
    10224.0
    10258.0
    [ft ]
    2
    10258.0
    10302.0
    [ft ]
    3
    10302.0
    10344.0
    [ft ]
    4
    10359.0
    10379.0
    [ft ]
    5
    10380.0
    10396.0
    [ft ]
    6
    10405.0
    10448.0
    [ft ]
    7
    10448.0
    10474.0
    [ft ]
    8
    10477.0
    10517.0
    [ft ]
    9
    10517.0
    10535.0
    [ft ]
    10
    10563.0
    10580.0
    [ft ]
    11
    10605.0
    10651.0
    [ft ]
    12
    10651.0
    10679.0
    [ft ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    114.0
    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
    3174.5
    [m]
    C
    OD
    3185.0
    [m]
    C
    OD
    3185.6
    [m]
    C
    OD
    3188.2
    [m]
    C
    OD
    3190.3
    [m]
    C
    OD
    3210.2
    [m]
    C
    OD

  • Oil samples at the Norwegian Offshore Directorate
    Oil samples at the Norwegian Offshore Directorate
    Test type
    Bottle number
    Top depth
    MD [m]
    Bottom depth
    MD [m]
    Fluid type
    Test time
    Samples available
    DST
    0.00
    0.00
    YES
    DST
    0.00
    0.00
    OIL
    YES

  • Lithostratigraphy
    Lithostratigraphy
    Top depth [mMD RKB]
    Lithostrat. unit
    99
    1749
    2945
    2945
    2961
    3008
    3077
    3096
    3096
    3186

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.28

  • 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
    18.33

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    3266
    3292
    0.0
    2.0
    3197
    3220
    0.0
    3.0
    3149
    3170
    0.0
    4.0
    3127
    3145
    0.0
    5.0
    3106
    3114
    0.0
    6.0
    3106
    3114
    0.0
    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
    5.0
    6.0
    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
    1054
    27183
    3.0
    200
    7079
    4.0
    5.0
    7
    736
    6.0
    8
    1444

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    BHC
    488
    3351
    CBL
    1033
    2429
    CBL
    2347
    3242
    CBL
    2371
    3326
    CDM
    2429
    3355
    CDM AP PP
    1208
    2438
    DL
    3048
    3352
    FDC
    3061
    3355
    GR
    107
    3351
    GR NL
    3018
    3328
    IES
    488
    3356
    PML C
    3049
    3356
    VELOCITY
    488
    3352

  • 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
    177.0
    36
    187.0
    0.00
    LOT
    INTERM.
    20
    610.0
    26
    622.0
    1.86
    LOT
    INTERM.
    13 3/8
    2093.0
    17 1/2
    2110.0
    1.88
    LOT
    INTERM.
    9 5/8
    3383.0
    12 1/4
    3390.0
    0.00
    LOT
    LINER
    7
    3710.0
    8 1/2
    3723.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    132
    1.07
    seawater
    487
    1.31
    waterbased
    1219
    1.49
    45.0
    waterbased
    2438
    1.71
    47.0
    waterbased
    3353
    1.71
    48.0
    waterbased