Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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25.11.2024 - 01:30
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2/3-3

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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.
    2/3-3
    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).
    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.
    2/3-3
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    LINE 13.
    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.
    Norske Murphy Oil Company
    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.
    61-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.
    44
    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,
    08.10.1971
    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.
    20.11.1971
    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.
    20.11.1973
    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.
    24.09.2004
    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.
    31.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    56.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2973.0
    Final vertical depth (TVD) [m RKB]
    Vertical elevation from total depth to kelly bushing. Shown only for released wells. Referred to as true vertical depth (TVD).
    2973.0
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    73
    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 PERMIAN
    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.
    ZECHSTEIN GP
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    56° 48' 18.9'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    3° 58' 11.5'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6296267.73
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    559226.21
    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.
    198

  • Wellbore history
    General
    Well 2/3-3 is located east of the Steinbit Terrace on the Sørvestlandet High. The main targets for the well were Danian limestones, Jurassic sands, and Oligocene sands.
    Operations and results
    Wildcat well 2/3-3 was spudded with the Jack-up installation Ocean Tide on 8 October 1971 and drilled to TD at in Late Permian Zechstein salt. Operations went without major problems except for some delays due to bad weather (on 17 November with winds in excess of 40 m/s and seas up to 17 m). The well was drilled with Bentonite and salt gel down to 269 m and with Spersene mud with 2% - 6.5% diesel from 269 m to TD.
    The well drilled a thick Tertiary/Quaternary section, mainly represented by grey sandy clays of Pliocene and Pleistocene age and by brown clays and mudstones of Oligocene to Miocene age. The Paleocene and Early Eocene consisted of varicoloured clays. No potential reservoirs (sands, sandstones and limestones) were found in the Tertiary.
    A moderate thickness (235 m) of Chalk was penetrated. The top 41 m was of Danian age (Ekofisk Formation, the remainder was of Santonian-Maastrichtian age (Tor and Hod Formations). One hundred and forty seven meters of Early Cretaceous rested on Kimmeridgian shales. From the base of the Kimmeridgian downwards, the section was poorly fossiliferous and only tentatively dated. The only shows observed were elevated methane readings in sand stringers in the interval 400 m to 900 m and in shales below this depth. No liquid hydrocarbons were observed in any part of the well. No cores were cut and no fluid samples taken. The well was abandoned as dry on 20 November 1971.
    Testing
    No drill stem test was performed

  • Cuttings at the Norwegian Offshore Directorate
    Cuttings at the Norwegian Offshore Directorate
    Cuttings available for sampling?
    NO
    Cuttings at the Norwegian Offshore Directorate
    Cutting sample, top depth [m]
    Cutting samples, bottom depth [m]
    280.42
    2966.92

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    4720.0
    [ft]
    DC
    RRI
    4750.0
    [ft]
    DC
    RRI
    4785.0
    [ft]
    DC
    RRI
    4800.0
    [ft]
    DC
    RRI
    4815.0
    [ft]
    DC
    RRI
    4830.0
    [ft]
    DC
    RRI
    4845.0
    [ft]
    DC
    RRI
    4860.0
    [ft]
    DC
    RRI
    4875.0
    [ft]
    DC
    RRI
    4890.0
    [ft]
    DC
    RRI
    4905.0
    [ft]
    DC
    RRI
    4920.0
    [ft]
    DC
    RRI
    4935.0
    [ft]
    DC
    RRI
    4950.0
    [ft]
    DC
    RRI
    4965.0
    [ft]
    DC
    RRI
    4980.0
    [ft]
    DC
    RRI
    4995.0
    [ft]
    DC
    RRI
    5010.0
    [ft]
    DC
    RRI
    5025.0
    [ft]
    DC
    RRI
    5040.0
    [ft]
    DC
    RRI
    5055.0
    [ft]
    DC
    RRI
    5070.0
    [ft]
    DC
    RRI
    5085.0
    [ft]
    DC
    RRI
    5115.0
    [ft]
    DC
    RRI
    5130.0
    [ft]
    DC
    RRI
    5145.0
    [ft]
    DC
    RRI
    5160.0
    [ft]
    DC
    RRI
    5175.0
    [ft]
    DC
    RRI
    5190.0
    [ft]
    DC
    RRI
    5205.0
    [ft]
    DC
    RRI
    5250.0
    [ft]
    DC
    RRI
    5295.0
    [ft]
    DC
    RRI
    5340.0
    [ft]
    DC
    RRI
    5385.0
    [ft]
    DC
    RRI
    5430.0
    [ft]
    DC
    RRI
    5475.0
    [ft]
    DC
    RRI
    5520.0
    [ft]
    DC
    RRI
    5550.0
    [ft]
    DC
    RRI
    5610.0
    [ft]
    DC
    RRI
    5655.0
    [ft]
    DC
    RRI
    5700.0
    [ft]
    DC
    RRI
    5740.0
    [ft]
    DC
    RRI
    5805.0
    [ft]
    DC
    RRI
    5850.0
    [ft]
    DC
    RRI
    5910.0
    [ft]
    DC
    RRI
    5955.0
    [ft]
    DC
    RRI
    6000.0
    [ft]
    DC
    RRI
    6060.0
    [ft]
    DC
    RRI
    6105.0
    [ft]
    DC
    RRI
    6150.0
    [ft]
    DC
    RRI
    6210.0
    [ft]
    DC
    RRI
    6255.0
    [ft]
    DC
    RRI
    6300.0
    [ft]
    DC
    RRI
    6360.0
    [ft]
    DC
    RRI
    6405.0
    [ft]
    DC
    RRI
    6465.0
    [ft]
    DC
    RRI
    6510.0
    [ft]
    DC
    RRI
    6540.0
    [ft]
    DC
    RRI
    6645.0
    [ft]
    DC
    RRI
    6700.0
    [ft]
    DC
    RRI
    6750.0
    [ft]
    DC
    RRI
    6810.0
    [ft]
    DC
    RRI
    6855.0
    [ft]
    DC
    RRI
    6900.0
    [ft]
    DC
    RRI
    6960.0
    [ft]
    DC
    RRI
    7000.0
    [ft]
    DC
    RRI
    7050.0
    [ft]
    DC
    RRI
    7110.0
    [ft]
    DC
    RRI
    7155.0
    [ft]
    DC
    RRI
    7200.0
    [ft]
    DC
    RRI
    7335.0
    [ft]
    DC
    RRI
    7350.0
    [ft]
    DC
    RRI
    7410.0
    [ft]
    DC
    RRI
    7455.0
    [ft]
    DC
    RRI
    7485.0
    [ft]
    DC
    RRI
    7500.0
    [ft]
    DC
    RRI
    7560.0
    [ft]
    DC
    RRI
    7605.0
    [ft]
    DC
    RRI
    7635.0
    [ft]
    DC
    RRI
    7650.0
    [ft]
    DC
    RRI
    7680.0
    [ft]
    DC
    RRI
    7755.0
    [ft]
    DC
    RRI
    7770.0
    [ft]
    DC
    RRI
    7800.0
    [ft]
    DC
    RRI
    7830.0
    [ft]
    DC
    RRI
    7860.0
    [ft]
    DC
    RRI
    7905.0
    [ft]
    DC
    RRI
    7950.0
    [ft]
    DC
    RRI
    8025.0
    [ft]
    DC
    RRI
    8055.0
    [ft]
    DC
    RRI
    8115.0
    [ft]
    DC
    RRI
    9270.0
    [ft]
    DC
    SNEA
    9315.0
    [ft]
    DC
    SNEA
    9390.0
    [ft]
    DC
    SNEA
    9405.0
    [ft]
    DC
    SNEA
    9480.0
    [ft]
    DC
    SNEA
    9510.0
    [ft]
    DC
    SNEA
    9600.0
    [ft]
    DC
    SNEA
    9645.0
    [ft]
    DC
    SNEA

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.32

  • 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
    4.63
    pdf
    2.66
    pdf
    0.64
    pdf
    0.95

  • Documents – Norwegian Offshore Directorate papers
    Documents – Norwegian Offshore Directorate papers
    Document name
    Document format
    Document size [MB]
    pdf
    19.10
    pdf
    46.58

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CST
    97
    2973
    DIL LL
    1084
    2972
    FDC GR CAL
    2913
    2972
    GR
    91
    2970
    GR SON CAL
    1084
    2970
    HRDIP
    1084
    2972

  • 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
    123.0
    36
    123.0
    0.00
    LOT
    INTERM.
    20
    264.0
    26
    279.0
    0.00
    LOT
    INTERM.
    13 3/8
    1084.0
    17 1/2
    1098.0
    0.00
    LOT
    OPEN HOLE
    2973.0
    12 1/4
    2973.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    278
    1.04
    40.0
    seawater
    1097
    1.43
    65.0
    seawater
    1940
    1.50
    55.0
    seawater
    2669
    1.57
    58.0
    seawater