Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
22.12.2024 - 01:25
Time of last synchronization with Norwegian Offshore Directorate's internal systems

2/4-2

Export: PDF icon PDF

  • General information
    General information
    Attribute Value
    Wellbore name
    Official name of wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    2/4-2
    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.
    2/4-2
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    LINE PG-0312 SP: 698.
    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.
    34-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.
    98
    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,
    18.09.1969
    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.
    24.12.1969
    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.
    24.12.1971
    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.
    27.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    70.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3305.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    6.75
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    133
    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' 8.65'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    3° 11' 54.57'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6265865.23
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    512208.29
    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.
    172

  • Wellbore history
    General
    Wildcat well 2/4-2 (originally termed 2/4-1AX by the License) was drilled by Phillips as a replacement for well 2/4-1, which was junked at 1662 m in Miocene sediments due to an oil kick and severe circulation problems. The objective was to test the hydrocarbon potential of the Tertiary and top Cretaceous.
    Operations and results
    Wildcat well 2/4-2 was spudded with the semi-submersible installation Ocean Viking on 18 September 1969 and drilled to TD at 3305 m in the Late Cretaceous Tor Formation. No significant problems occurred in the operations. The well was drilled with seawater and hi-vis pills down to 619 m, and with lignosulphonate mud from 619 m to TD.
    The well discovered oil in Danian and Late Cretaceous chalk (Ekofisk and Tor Formations). The oil was found in two reservoirs separated by a hard, grey and tight lime mudstone in the base of the Ekofisk Formation. The upper, Ekofisk Formation reservoir was encountered at 3033 m and continued down to the tight lime mudstone at 3183 m. The lower, Tor Formation reservoir extended from 3203 m to 3257 m. Comparison between DST oil from the Ekofisk Formation in well 2/4-2 and the Miocene "kick-oil" encountered in well 2/4-1 showed that the 2/4-1 Miocene oil is a heavier oil with a higher asphaltene content and lower paraffin content than the 2/4-2 oil.
    Eight conventional cores were cut with a total of 48.5 m recovered. Core 1 was cut in Early Miocene from 1664 to 1679.4 m, while cores 2 - 8 were cut in the Ekofisk and Tor Formations in the interval 3051 m to 3280 m. No wire line fluid samples were taken
    The well was suspended on 24 December 1969 as the Ekofisk Discovery well, the first economic petroleum discovery on the Norwegian Continental Shelf.
    Testing
    One successful drill stem tests (DST 4) was conducted in open hole in the interval 3159 to 3195.5 m at the base of the Ekofisk Formation. It flowed 5.9 MMCFD (167069 Sm3) gas and 1071 BPD (170 Sm3) oil on a 34/64" choke. The GOR was reported as 5500 cu.ft./STB (980 Sm3/Sm3). The oil had an API gravity of 37.2 deg. The reservoir temperature was reported to be 265 deg F (129.4 deg C).

  • 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]
    838.20
    3304.03

  • 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
    10010.0
    10017.0
    [ft ]
    3
    10496.0
    10510.0
    [ft ]
    4
    10515.0
    10528.0
    [ft ]
    5
    10565.0
    10573.0
    [ft ]
    6
    10605.0
    10621.5
    [ft ]
    7
    10653.0
    10657.0
    [ft ]
    8
    10713.0
    10755.0
    [ft ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    31.9
    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
    5980.0
    [ft]
    DC
    6220.0
    [ft]
    DC
    6250.0
    [ft]
    DC
    6280.0
    [ft]
    DC
    6300.0
    [ft]
    DC
    6330.0
    [ft]
    DC
    6410.0
    [ft]
    DC
    6440.0
    [ft]
    DC
    6480.0
    [ft]
    DC
    6580.0
    [ft]
    DC
    6630.0
    [ft]
    DC
    6690.0
    [ft]
    DC
    6750.0
    [ft]
    DC
    6810.0
    [ft]
    DC
    6870.0
    [ft]
    DC
    6900.0
    [ft]
    DC
    6930.0
    [ft]
    DC
    6960.0
    [ft]
    DC
    7020.0
    [ft]
    DC
    7100.0
    [ft]
    DC
    7160.0
    [ft]
    DC
    7210.0
    [ft]
    DC
    7260.0
    [ft]
    DC
    7330.0
    [ft]
    DC
    7420.0
    [ft]
    DC
    7480.0
    [ft]
    DC
    7540.0
    [ft]
    DC
    7600.0
    [ft]
    DC
    7690.0
    [ft]
    DC
    7750.0
    [ft]
    DC
    7820.0
    [ft]
    DC
    7880.0
    [ft]
    DC
    7940.0
    [ft]
    DC
    8000.0
    [ft]
    DC
    8090.0
    [ft]
    DC
    8150.0
    [ft]
    DC
    8210.0
    [ft]
    DC
    8270.0
    [ft]
    DC
    8330.0
    [ft]
    DC
    8390.0
    [ft]
    DC
    8450.0
    [ft]
    DC
    8510.0
    [ft]
    DC
    8570.0
    [ft]
    DC
    8620.0
    [ft]
    DC
    8680.0
    [ft]
    DC
    8750.0
    [ft]
    DC
    8810.0
    [ft]
    DC
    8840.0
    [ft]
    DC
    8900.0
    [ft]
    DC
    8960.0
    [ft]
    DC
    9020.0
    [ft]
    DC
    9080.0
    [ft]
    DC
    9120.0
    [ft]
    DC
    9180.0
    [ft]
    DC
    9240.0
    [ft]
    DC
    9330.0
    [ft]
    DC
    9390.0
    [ft]
    DC
    9450.0
    [ft]
    DC
    9500.0
    [ft]
    DC
    9560.0
    [ft]
    DC
    9650.0
    [ft]
    DC
    9710.0
    [ft]
    DC
    9770.0
    [ft]
    DC
    9840.0
    [ft]
    DC
    9890.0
    [ft]
    DC
    9940.0
    [ft]
    DC
    9980.0
    [ft]
    DC
    10020.0
    [ft]
    DC
    10060.0
    [ft]
    DC
    10100.0
    [ft]
    DC
    10140.0
    [ft]
    DC
    10180.0
    [ft]
    DC
    10221.0
    [ft]
    C
    10230.0
    [ft]
    DC
    10240.0
    [ft]
    DC
    10260.0
    [ft]
    DC
    10350.0
    [ft]
    DC
    10365.0
    [ft]
    DC
    10410.0
    [ft]
    DC
    10430.0
    [ft]
    DC
    10470.0
    [ft]
    DC
    10485.0
    [ft]
    DC
    10505.0
    [ft]
    DC
    10520.0
    [ft]
    DC
    10550.0
    [ft]
    DC
    10600.0
    [ft]
    DC
    10620.0
    [ft]
    DC
    10640.0
    [ft]
    DC
    10675.0
    [ft]
    C
    10720.0
    [ft]
    DC
    10800.0
    [ft]
    DC
    10840.0
    [ft]
    DC
    10860.0
    [ft]
    DC
    10876.0
    [ft]
    C
    10926.0
    [ft]
    C
    11000.0
    [ft]
    DC
    11045.0
    [ft]
    DC
    11100.0
    [ft]
    DC
    11150.0
    [ft]
    DC
    11200.0
    [ft]
    DC
    11240.0
    [ft]
    DC
    11250.0
    [ft]
    DC

  • Lithostratigraphy
    Lithostratigraphy
    Top depth [mMD RKB]
    Lithostrat. unit
    98
    1682
    2904
    2904
    2911
    2970
    3017
    3050
    3050
    3203

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.29

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.34
    pdf
    1.28

  • 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
    11.04
    pdf
    3.43
    pdf
    11.08
    pdf
    6.02
    pdf
    3.29
    pdf
    0.17
    pdf
    43.44
    pdf
    30.92
    pdf
    2.55
    pdf
    25.72
    pdf
    8.81
    pdf
    5.15
    pdf
    4.25
    pdf
    7.28

  • Documents – Norwegian Offshore Directorate papers
    Documents – Norwegian Offshore Directorate papers
    Document name
    Document format
    Document size [MB]
    pdf
    18.62
    pdf
    1.95
    pdf
    1.18

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    3160
    3196
    25.4
    2.0
    3160
    3196
    0.0
    3.0
    3160
    3196
    0.0
    4.0
    3148
    3160
    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
    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
    1089
    2.0
    3.0
    4.0
    170
    167067
    0.839

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    AC GR CAL
    580
    3302
    CBL
    2295
    3154
    DIP
    2365
    3155
    FDC
    2865
    3304
    IEL
    580
    3305
    LL
    2865
    3304
    MLL
    2865
    3304
    NEU POR
    2865
    3304
    TEMP
    40
    3305

  • 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
    132.0
    36
    133.0
    0.00
    LOT
    SURF.COND.
    20
    581.0
    26
    581.0
    0.00
    LOT
    INTERM.
    13 3/8
    1607.0
    17 1/2
    1607.0
    0.00
    LOT
    INTERM.
    9 5/8
    2366.0
    12 1/4
    2366.0
    0.00
    LOT
    LINER
    7
    3159.0
    8 1/2
    3159.0
    0.00
    LOT
    LINER
    5
    3305.0
    6
    3305.0
    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
    1.15
    85.0
    spud-mud
    655
    1.55
    45.0
    spud-mud
    1150
    1.64
    50.0
    spud-mud
    1616
    1.67
    50.0
    water-based
    2377
    1.71
    50.0
    water-based
    3039
    1.61
    45.0
    water-based
    3265
    1.66
    45.0
    water-based
    3305
    1.67
    47.0
    water-based

  • 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 ]