Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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2/3-1

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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.
    2/3-1
    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
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    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
    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.
    2/3-1
    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.
    23-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.
    53
    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,
    10.02.1969
    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.
    03.04.1969
    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.
    03.04.1971
    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.
    29.06.2004
    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.
    GAS
    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.
    OLIGOCENE
    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.
    VADE 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.
    59.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2934.0
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    90
    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° 53' 9.46'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    3° 51' 38.08'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6305162.64
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    552439.87
    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.
    162

  • Wellbore history
    General
    Well 2/3-1 is located approximately in the centre of the block on the Sørvestlandet High. The aim of the well was to test potential reservoirs in the Tertiary, Cretaceous, Jurassic, and Trias.
    Operations and results
    Wildcat well 2/3-1 was spudded with the semi-submersible installation Ocean Traveler on 10 February 1969 and drilled to TD at 2934 m in the Late Permian Zechstein Group. Bad weather with wind up to 31 m/s caused the rig to drift up to ca 40 feet off location on several occasions, interrupting drilling operations. The well was drilled with seawater and bentonite down to 463 m. A water based mud system was used in the remaining borehole.
    The well encountered gas in two zones in Oligocene. From log analyses most of the reservoir interval from 1623 m to 1636 m, except a shale break, had a porosity around 22% with Sw = 30%.á Best part of the second zone had a porosity of 23% with an Sw of 23%, (1597 m to 1600 m). No cores were cut in the well and no fluid samples were taken other than during the tests.
    The well was permanently abandoned as a gas discovery on 3 April 1969.
    Testing
    Seven inch casing was run to 1673 m and two flowing drill stem tests were made successfully.á The first test was made from perforations at 1624 m to 1636 m and flowed dry gas at rates of 207000 to 304000 Sm3/day on choke sizes varying from 24/64" to 30/64". The second test flowed dry gas at rates of 40000 to 92000/day on choke sizes varying from 12/64" to 3O/64" from perforations at 1588 m to 1600 m.

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    4980.0
    [ft]
    DC
    RRI
    5020.0
    [ft]
    DC
    RRI
    5100.0
    [ft]
    DC
    RRI
    5140.0
    [ft]
    DC
    RRI
    5180.0
    [ft]
    DC
    RRI
    5220.0
    [ft]
    DC
    RRI
    5300.0
    [ft]
    DC
    RRI
    5340.0
    [ft]
    DC
    RRI
    5380.0
    [ft]
    DC
    RRI
    5420.0
    [ft]
    DC
    RRI
    5500.0
    [ft]
    DC
    RRI
    5540.0
    [ft]
    DC
    RRI
    5580.0
    [ft]
    DC
    RRI
    5620.0
    [ft]
    DC
    RRI
    5700.0
    [ft]
    DC
    RRI
    5740.0
    [ft]
    DC
    RRI
    5780.0
    [ft]
    DC
    RRI
    5820.0
    [ft]
    DC
    RRI
    5900.0
    [ft]
    DC
    RRI
    5940.0
    [ft]
    DC
    RRI
    5980.0
    [ft]
    DC
    RRI
    6020.0
    [ft]
    DC
    RRI
    6100.0
    [ft]
    DC
    RRI
    6140.0
    [ft]
    DC
    RRI
    6180.0
    [ft]
    DC
    RRI
    6220.0
    [ft]
    DC
    RRI
    6300.0
    [ft]
    DC
    RRI
    6320.0
    [ft]
    DC
    RRI
    6380.0
    [ft]
    DC
    RRI
    6420.0
    [ft]
    DC
    RRI
    6500.0
    [ft]
    DC
    RRI
    6540.0
    [ft]
    DC
    RRI
    6580.0
    [ft]
    DC
    RRI
    6620.0
    [ft]
    DC
    RRI
    6700.0
    [ft]
    DC
    RRI
    6740.0
    [ft]
    DC
    RRI
    6780.0
    [ft]
    DC
    RRI
    6840.0
    [ft]
    DC
    RRI
    6880.0
    [ft]
    DC
    RRI
    6920.0
    [ft]
    DC
    RRI
    7000.0
    [ft]
    DC
    RRI
    7040.0
    [ft]
    DC
    RRI
    7080.0
    [ft]
    DC
    RRI
    7120.0
    [ft]
    DC
    RRI
    7180.0
    [ft]
    DC
    RRI
    7240.0
    [ft]
    DC
    RRI
    7280.0
    [ft]
    DC
    RRI
    8360.0
    [ft]
    DC
    SNEA
    8420.0
    [ft]
    DC
    SNEA
    9020.0
    [ft]
    DC
    SNEA
    9140.0
    [ft]
    DC
    SNEA
    9250.0
    [ft]
    DC
    SNEA
    9330.0
    [ft]
    DC
    SNEA
    9420.0
    [ft]
    DC
    SNEA
    9510.0
    [ft]
    DC
    SNEA
    9560.0
    [m]
    DC
    SNEA

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.31

  • 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
    13.07
    pdf
    4.39
    pdf
    0.46
    pdf
    2.73
    pdf
    1.08
    pdf
    40.06
    pdf
    2.48

  • Documents – Norwegian Offshore Directorate papers
    Documents – Norwegian Offshore Directorate papers
    Document name
    Document format
    Document size [MB]
    pdf
    19.10
    pdf
    46.29

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    1624
    1637
    11.5
    2.0
    1588
    1601
    11.5
    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
    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
    283100
    2.0
    50000

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    DENS
    1579
    1653
    GR SON CAL
    107
    2930
    IEL
    275
    2924
    LL
    275
    2395
    MLL CAL
    1158
    2865
    SNP
    1579
    1653

  • 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
    124.0
    0.00
    LOT
    INTERM.
    20
    275.0
    26
    277.0
    0.00
    LOT
    INTERM.
    13 3/8
    1298.0
    17 1/2
    1300.0
    0.00
    LOT
    INTERM.
    9 5/8
    1674.0
    12 1/4
    1674.0
    0.00
    LOT
    OPEN HOLE
    2934.0
    8 1/2
    2934.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    123
    1.02
    200.0
    spud mud
    463
    1.01
    108.0
    water based
    701
    1.11
    40.0
    water based
    1173
    1.30
    50.0
    water based
    1310
    1.37
    49.0
    water based
    1323
    1.37
    63.0
    water based
    1646
    1.44
    62.0
    water based
    2172
    1.41
    98.0
    water based