Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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31.12.2024 - 01:26
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2/4-3

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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.
    2/4-3
    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.
    2/4-3
    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.
    35-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.
    125
    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,
    27.01.1970
    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.
    31.05.1970
    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.
    31.05.1972
    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.
    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.
    27.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    71.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3431.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    16.4
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    138
    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° 32' 42.12'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    3° 14' 55.49'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6266910.18
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    515295.52
    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.
    97

  • Wellbore history
    General
    Well 2/4-3 (named 2/4-2X by operator Phillips) was drilled to appraise the 2/4-2 Ekofisk discovery in the southern Norwegian North Sea. The target was to test the Tertiary and the top of the Late Cretaceous.
    Operations and results
    Well 2/4-3 was spudded with the semi-submersible installation Ocean Viking on 27 January 1970 and drilled to TD at 3431 m in the Late Cretaceous Tor Formation. The well was planned vertical, but the deviation was significant. Maximum deviation was 1 deg  at 618 m, 3 deg  at 1077 m, 11.5 deg  at 1316 m, 16.4 deg  at 1605 m, 10 deg  at 2167 m, 4 deg  at 3002 m, and 1.7 deg at 3292 m. This indicates that TVD RKB is ca 30 m shallower than MD RKB at TD, but exact records are not available. The well was drilled with seawater and hi-vis mud down to 619 m, with CaCl2 / Dextrid (modified potato starch) from 619 m to 1695 m, and with lignosulphonate / seawater from 1695 m to TD. One - four percent diesel was added to the mud below 619 m.
    The Danian chalk (Ekofisk Formation) was encountered at 3090 m, and the Late Cretaceous chalk (Tor Formation) at 3253 m. The formations were tested hydrocarbon bearing from 3124 m to 3319 m.
    Eighteen conventional cores were cut in the well. Core 1was cut in the interval 1705 - 1717 m with only 0.6 m core recovered. Cores 2 - 13 were cut in the Danian chalk (Ekofisk Formation), while cores 14 - 18 were cut in the Maastrichtian chalk (Tor Formation). No fluid samples were taken on wire line.
    The well was permanently abandoned on 31 May 1970 as an oil appraisal.
    Testing
    Ten drill stem tests were carried out through perforations in the 7" liner. DST 1 and 2 tested the intervals 3352 - 3362 m and 3331 - 3341 in the in the Tor Formation. They produced only water. DST 3 to 9 tested different zones in the interval from 3124 to 3319 m in the Ekofisk and Tor Formations. They produced gas and oil. The oils were in the range 33.2 to 36 deg API and the GOR varied from 182 to 243 Sm3/Sm3. DST 10 tested the interval 3016 - 3024 m in the Sele Formation. It flowed 2.4 Sm3 of water, and then died. Reservoir temperatures at mid perforation were reported to be: 134.4 deg C (at 3317.7 m) in DST 3, 133.6 deg C (at 3281.2 m) in DST 4, and 132.2 deg C (at 3238.5 m) in DST 5.

  • 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]
    627.90
    3431.13

  • 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
    2
    10220.0
    10225.0
    [ft ]
    3
    10226.0
    10233.0
    [ft ]
    4
    10235.0
    10252.0
    [ft ]
    5
    10250.0
    10276.0
    [ft ]
    6
    10276.0
    10279.0
    [ft ]
    7
    10279.0
    10289.0
    [ft ]
    8
    10294.0
    10310.0
    [ft ]
    9
    10314.0
    10324.0
    [ft ]
    10
    10379.0
    10388.0
    [ft ]
    11
    10385.0
    10395.0
    [ft ]
    12
    10550.0
    10573.0
    [ft ]
    13
    10665.0
    10669.0
    [ft ]
    14
    10669.0
    10679.0
    [ft ]
    15
    10679.0
    10708.0
    [ft ]
    16
    10750.0
    10769.0
    [ft ]
    17
    10870.0
    10894.5
    [ft ]
    18
    10894.5
    10949.0
    [ft ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    84.4
    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
    10668.0
    [ft]
    C
    OD

  • Lithostratigraphy
    Lithostratigraphy
    Top depth [mMD RKB]
    Lithostrat. unit
    98
    1730
    2960
    2960
    2969
    2976
    3005
    3023
    3076
    3090
    3090
    3253

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.43

  • 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
    11.81
    pdf
    9.41
    pdf
    0.12
    pdf
    1.18
    pdf
    55.84
    pdf
    1.40
    pdf
    29.21
    pdf
    29.53
    pdf
    1.19
    pdf
    1.24
    pdf
    32.20
    pdf
    27.19
    pdf
    19.24

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    3354
    3363
    25.4
    2.0
    3332
    3341
    25.4
    3.0
    3317
    3320
    19.0
    4.0
    3268
    3296
    28.5
    5.0
    3235
    3244
    19.0
    6.0
    3195
    3226
    6.3
    7.0
    3195
    3226
    19.0
    8.0
    3139
    3148
    6.0
    9.0
    3124
    3154
    25.4
    10.0
    3124
    3224
    19.0
    11.0
    3015
    3023
    25.4
    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
    7.300
    27.500
    4.0
    5.0
    28.000
    6.0
    28.500
    46.000
    7.0
    28.000
    33.000
    8.0
    28.000
    46.000
    9.0
    28.000
    20.000
    10.0
    28.000
    38.000
    11.0
    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
    323
    58581
    0.855
    4.0
    328
    62967
    0.845
    5.0
    172
    36337
    0.853
    6.0
    166
    35799
    0.848
    7.0
    609
    129812
    0.854
    8.0
    186
    39337
    0.847
    9.0
    326
    79240
    0.849
    10.0
    595
    132925
    0.859
    11.0

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL
    2947
    3379
    CDM
    610
    3429
    CDS
    1402
    2012
    DIR
    607
    3430
    FDC
    1629
    3429
    GR
    98
    607
    GRN
    2942
    3372
    IES
    607
    3429
    LL-7
    3008
    3429
    MLL-C
    3008
    3429
    SGR
    607
    1629
    SGR-C
    1629
    3426
    SNP
    3008
    3429
    VDL
    2988
    3384
    VELOCITY
    607
    3426
    AA
    3008
    3425

  • 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
    131.0
    36
    131.0
    0.00
    LOT
    SURF.COND.
    20
    607.0
    26
    619.0
    0.00
    LOT
    INTERM.
    13 3/8
    1629.0
    17 1/2
    1633.0
    0.00
    LOT
    INTERM.
    9 5/9
    3007.0
    12 1/4
    3018.0
    0.00
    LOT
    LINER
    7
    3389.0
    8 1/2
    3432.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    619
    1.03
    seawater
    1153
    1.70
    cacl/broxin
    1632
    1.71
    seaw/broxin
    2320
    1.71
    seaw/broxin
    3018
    1.71
    seaw/broxin
    3225
    1.71
    seaw/broxin

  • Thin sections at the Norwegian Offshore Directorate
    Thin sections at the Norwegian Offshore Directorate
    Depth
    Unit
    10679.00
    [ft ]
    10685.00
    [ft ]
    10759.00
    [ft ]
    149.00
    [m ]
    150.00
    [m ]
    151.00
    [m ]
    156.00
    [m ]
    157.00
    [m ]
    160.00
    [m ]
    161.00
    [m ]
    162.00
    [m ]
    165.00
    [m ]
    170.00
    [m ]