Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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22.11.2024 - 09:09
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1/6-4

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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.
    1/6-4
    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
    Well name
    Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    1/6-4
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    LINE 002425 SP.6977
    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.
    A/S Norske Shell
    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.
    144-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.
    103
    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,
    29.12.1975
    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.
    09.04.1976
    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.
    09.04.1978
    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.
    15.06.2011
    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.
    DRY
    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.
    33.0
    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).
    3810.0
    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° 44' 52.06'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 42' 23.64'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6289490.96
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    482053.29
    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.
    242

  • Wellbore history
    General
    Well 1/6-4 was drilled in the southernmost part of the Breiflabb Basin in the North Sea. The objective was to evaluate a large low relief base Tertiary - Late Cretaceous structure with potential reservoirs both in the Danian - Late Cretaceous Chalk and in the Paleocene Sands. The primary target was the Chalk (Ekofisk and Tor formations).
    Operations and results
    Wildcat well 1/6-4 was spudded with the semi-submersible installation Chris Chenery on 29 December 1975 and drilled to TD at 3810 m in the Late Cretaceous Tor Formation. The drilling of 1/6-4 was beset with rig mechanical problems, most notably failures in the mooring system induced by adverse North Sea weather. All in all 34 days (ca 33%) of the total rig time on the well was counted as down time. The well was drilled with bentonite/seawater spud mud down to 437 m and with lime/Drispac/seawater mud from 437 m to TD.
    Top Rogaland Group, Balder Formation, came in at 3110 m. A Paleocene sandstone, Andrew Formation was penetrated from 3197 to 3253 m. Top Shetland Group, Ekofisk Formation, came in at 3374 m. The Balder Formation (Tuff marker) had some residual hydrocarbons up to 30%. This was substantiated by gas readings and some shows of fluorescence in ditch cuttings. The underlying Andrew Formation sandstones were found 100% water-bearing. Both the Danian and Maastrichtian were fully water bearing based on petrophysical analyses. This was in agreement with the lack of oil/gas shows while drilling in this section.
    No cores were cut and no wire line fluid samples were taken.
    The well was permanently abandoned on 9 April 1978 as a dry well with shows.
    Testing
    No drill stem test was performed.

  • 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]
    192.00
    3810.00

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    8000.0
    [ft]
    DC
    RRI
    8060.0
    [ft]
    DC
    RRI
    8120.0
    [ft]
    DC
    RRI
    8180.0
    [ft]
    DC
    RRI
    8240.0
    [ft]
    DC
    RRI
    8300.0
    [ft]
    DC
    RRI
    8360.0
    [ft]
    DC
    RRI
    8420.0
    [ft]
    DC
    RRI
    8480.0
    [ft]
    DC
    RRI
    8540.0
    [ft]
    DC
    RRI
    8600.0
    [ft]
    DC
    RRI
    8620.0
    [ft]
    DC
    RRI
    8660.0
    [ft]
    DC
    RRI
    8680.0
    [ft]
    DC
    RRI
    8720.0
    [ft]
    DC
    RRI
    8740.0
    [ft]
    DC
    RRI
    8780.0
    [ft]
    DC
    RRI
    8800.0
    [ft]
    DC
    RRI
    8840.0
    [ft]
    DC
    RRI
    8860.0
    [ft]
    DC
    RRI
    8900.0
    [ft]
    DC
    RRI
    8920.0
    [ft]
    DC
    RRI
    8960.0
    [ft]
    DC
    RRI
    8980.0
    [ft]
    DC
    RRI
    9020.0
    [ft]
    DC
    RRI
    9040.0
    [ft]
    DC
    RRI
    9080.0
    [ft]
    DC
    RRI
    9100.0
    [ft]
    DC
    RRI
    9140.0
    [ft]
    DC
    RRI
    9160.0
    [ft]
    DC
    RRI
    9200.0
    [ft]
    DC
    RRI
    9220.0
    [ft]
    DC
    RRI
    9260.0
    [ft]
    DC
    RRI
    9270.0
    [ft]
    DC
    RRI
    9320.0
    [ft]
    DC
    RRI
    9330.0
    [ft]
    DC
    RRI
    9380.0
    [ft]
    DC
    RRI
    9410.0
    [ft]
    DC
    RRI
    9450.0
    [ft]
    DC
    RRI
    9480.0
    [ft]
    DC
    RRI
    9500.0
    [ft]
    DC
    RRI
    9520.0
    [ft]
    DC
    RRI
    9560.0
    [ft]
    DC
    RRI
    9600.0
    [ft]
    DC
    RRI
    9620.0
    [ft]
    DC
    RRI
    9680.0
    [ft]
    DC
    RRI
    9700.0
    [ft]
    DC
    RRI
    9740.0
    [ft]
    DC
    RRI
    9760.0
    [ft]
    DC
    RRI
    9800.0
    [ft]
    DC
    RRI
    9840.0
    [ft]
    DC
    RRI
    9860.0
    [ft]
    DC
    RRI
    9920.0
    [ft]
    DC
    RRI
    9960.0
    [ft]
    DC
    RRI
    9980.0
    [ft]
    DC
    RRI
    10020.0
    [ft]
    DC
    RRI
    10040.0
    [ft]
    DC
    RRI
    10080.0
    [ft]
    DC
    RRI
    10140.0
    [ft]
    DC
    RRI
    10180.0
    [ft]
    DC
    RRI
    10200.0
    [ft]
    DC
    RRI
    10220.0
    [ft]
    DC
    RRI
    10260.0
    [ft]
    DC
    RRI
    10300.0
    [ft]
    DC
    RRI
    10320.0
    [ft]
    DC
    RRI
    10340.0
    [ft]
    DC
    RRI
    10380.0
    [ft]
    DC
    RRI
    10400.0
    [ft]
    DC
    RRI
    10440.0
    [ft]
    DC
    RRI
    10450.0
    [ft]
    DC
    RRI
    10500.0
    [ft]
    DC
    RRI
    10510.0
    [ft]
    DC
    RRI
    10560.0
    [ft]
    DC
    RRI
    10600.0
    [ft]
    DC
    RRI
    10620.0
    [ft]
    DC
    RRI
    10670.0
    [ft]
    DC
    RRI
    10680.0
    [ft]
    DC
    RRI
    10720.0
    [ft]
    DC
    RRI
    10730.0
    [ft]
    DC
    RRI
    10770.0
    [ft]
    DC
    RRI
    10790.0
    [ft]
    DC
    RRI
    10820.0
    [ft]
    DC
    RRI
    10850.0
    [ft]
    DC
    RRI
    10900.0
    [ft]
    DC
    RRI
    10910.0
    [ft]
    DC
    RRI
    10960.0
    [ft]
    DC
    RRI
    10970.0
    [ft]
    DC
    RRI
    11020.0
    [ft]
    DC
    RRI
    11030.0
    [ft]
    DC
    RRI
    11080.0
    [ft]
    DC
    RRI
    11090.0
    [ft]
    DC
    RRI
    11150.0
    [ft]
    DC
    RRI
    11220.0
    [ft]
    DC
    RRI
    11280.0
    [ft]
    DC
    RRI
    11340.0
    [ft]
    DC
    RRI
    11410.0
    [ft]
    DC
    RRI

  • Lithostratigraphy
    Lithostratigraphy
    Top depth [mMD RKB]
    Lithostrat. unit
    105
    1633
    3110
    3110
    3124
    3130
    3197
    3253
    3335
    3374
    3374
    3475

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.05
    pdf
    0.69

  • 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
    1.62
    pdf
    25.70

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    BGT
    594
    1431
    BGT
    1409
    2947
    BHC GR
    1409
    4036
    BHC GR CAL
    4023
    10775
    BHC GR CAL
    10736
    12498
    DLL GR
    10737
    12484
    DLL SP
    4023
    10765
    FDC CNL CAL
    4026
    10776
    FDC CNL GR CAL
    10737
    12500
    IES GR
    4024
    10778

  • 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
    181.0
    36
    187.0
    0.00
    LOT
    INTERM.
    20
    429.0
    26
    437.0
    0.00
    LOT
    INTERM.
    13 3/8
    1224.0
    17 1/2
    1232.0
    0.00
    LOT
    INTERM.
    9 5/8
    3272.0
    12 1/4
    3285.0
    0.00
    LOT
    OPEN HOLE
    3810.0
    8 1/2
    3810.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    173
    1.54
    seawt/bento
    435
    1.55
    seawt/bento
    1228
    1.55
    seawt/bento
    3283
    1.56
    seawt/lime
    3810
    1.56
    seawt/lime