Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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27.11.2024 - 01:27
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2/4-7

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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.
    2/4-7
    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).
    APPRAISAL
    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.
    2/4-7
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    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.
    59-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.
    77
    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,
    24.07.1971
    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.
    08.10.1971
    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.
    08.10.1973
    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.
    02.04.2007
    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.
    APPRAISAL
    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.
    NO
    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.
    LATE CRETACEOUS
    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.
    TOR FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    34.0
    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).
    3494.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    0.75
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    142
    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.
    HOD FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    56° 38' 5.4'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    3° 16' 45.3'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6276913.21
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    517130.46
    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.
    196

  • Wellbore history
    General
    Well 2/4-7 was drilled on a structure ca six km west off the Ekofisk discovery. The objective of the well was to test the Danian limestone with estimated 200 m gross / 120 m net pay, and the Late Cretaceous limestone with estimated 60 m gross / 15 m net pay. These Formations had proved oil productive in the other wells on the Tor structure. Secondary objective was possible Paleocene sand in the interval 3020 - 3140 m. Planned depth was 3414 m (11200 ft).
    Operations and results
    Appraisal well 2/4-7 was spudded with the jack-up installation M ærsk Explorer on and drilled to TD at 3493 m in the Late Cretaceous Tor Formation. The drill pipe stuck at 3405 m, but was freed after seven hours working. The well was drilled with seawater and gel down to 555 m and with seawater/drill aid and 2 - 5% diesel from 555 m to TD.
    Top Paleocene (Balder Formation) was encountered at 3048 m. The Paleocene contained only minor, thin sand beds. The chalk group came in with the Ekofisk Formation at 3175 m and the Tor Formation at 3304 m. Fair shows were recorded on cores in the top 2 m of the Ekofisk Formation, otherwise Ekofisk only had scattered shows. Fair to good shows were again recorded in the Tor Formation, from the top and down to 3332 m. Below this depth shows were reported as spotty, on fracture plains. Oil was confirmed by testing in the top 24 m of the Tor Formation. The test in top Ekofisk gave only water with a trace of gas. Thirteen cores were cut in the well, recovering a total of 164 m core. Core 1 to 9 were cut throughout the Ekofisk Formation, the rest were cut in the upper part of the Tor Formation. Core depths were reported to be 4 - 5 m shallower than log depth for all cores except core 5, which need to be shifted only + 1 m. No wire line fluid samples were taken.
    The well was permanently abandoned on 18 October as an oil appraisal.
    Testing
    Seven drill stem tests were carried out through perforations in the 7" liner. DST 1, 2, and 3 were conducted in the Tor Formation, the rest in the Ekofisk Formation. The following results are after acidization of the formation. DST 1 from 3367 - 3370 m flowed 229 m3 water /day. DST 2 from 3345 - 3348 m flowed only water cushion to surface and died after 50 min. DST 3 from 3304 - 3313 and 3319 - 3328 m flowed 551 Sm3 oil, 73620 Sm3 gas, and 164 Sm3 water /day. The GOR was 137 Sm3/Sm3 and the oil gravity was 38.2 deg API. The tests in the Ekofisk Formation gave water with only a trace of gas in the interval 3176 - 3203 m in DST 5. The reported DST temperatures are somewhat erratic but were all higher than BHT's from well logging from similar depths. The reported temperatures from the best flows, DST 1 and DST 3, were 138 and 129 deg C, respectively.

  • 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]
    566.93
    3486.91

  • 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
    10405.0
    10445.0
    [ft ]
    2
    10445.0
    10483.0
    [ft ]
    3
    10483.0
    10532.0
    [ft ]
    4
    10532.0
    10579.0
    [ft ]
    5
    10579.0
    10615.0
    [ft ]
    6
    10630.0
    10660.0
    [ft ]
    7
    10670.0
    10708.0
    [ft ]
    8
    10707.0
    10766.5
    [ft ]
    9
    10767.0
    10814.0
    [ft ]
    10
    10814.0
    10830.0
    [ft ]
    11
    10874.0
    10880.0
    [ft ]
    12
    10904.0
    10924.5
    [ft ]
    13
    10934.0
    10955.0
    [ft ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    136.6
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Lithostratigraphy
    Lithostratigraphy
    Top depth [mMD RKB]
    Lithostrat. unit
    102
    1736
    3048
    3048
    3060
    3070
    3162
    3175
    3175
    3304

  • 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
    24.23
    pdf
    24.23
    pdf
    0.08
    pdf
    9.74
    pdf
    34.66
    pdf
    252.67
    pdf
    1.38
    pdf
    1.92
    pdf
    15.31
    pdf
    0.25
    pdf
    6.72
    pdf
    20.46
    pdf
    4.64
    pdf
    0.72
    pdf
    0.93
    pdf
    2.70
    pdf
    101.99
    pdf
    8.96
    pdf
    4.51
    pdf
    4.04
    pdf
    11.62
    pdf
    3.75
    pdf
    4.43
    pdf
    3.68
    pdf
    10.17

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    3367
    3370
    0.0
    2.0
    3346
    3349
    0.0
    3.0
    3304
    3329
    0.0
    4.0
    3250
    3261
    0.0
    5.0
    3176
    3204
    0.0
    6.0
    3176
    3182
    0.0
    7.0
    3189
    3204
    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
    138
    2.0
    139
    3.0
    129
    4.0
    5.0
    6.0
    7.0
    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
    551
    736231
    4.0
    5.0
    6.0
    7.0

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    BHC GR
    559
    3491
    CBL
    427
    3146
    CBL GR
    3049
    3480
    FDC
    3145
    3494
    GR
    107
    559
    GR N
    3049
    3480
    HDT
    3145
    3493
    IES
    556
    3494
    LL-7
    3146
    3494
    PROX ML
    3146
    3493
    SNP
    3176
    3494
    WSC
    1164
    3489

  • 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
    136.0
    36
    136.0
    0.00
    LOT
    SURF.COND.
    20
    557.0
    26
    564.0
    0.00
    LOT
    INTERM.
    13 3/8
    1587.0
    17 1/2
    1591.0
    0.00
    LOT
    INTERM.
    9 5/8
    3147.0
    12 1/4
    3155.0
    0.00
    LOT
    LINER
    7
    3488.0
    8 1/2
    3488.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    186
    1.12
    seaw/ligno
    564
    1.36
    seaw/ligno
    1362
    1.72
    seaw/ligno
    2835
    1.71
    seaw/ligno
    3155
    1.71
    seaw/ligno
    3333
    1.72
    seaw/ligno