Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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23.07.2024 - 01:26
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2/2-3

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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.
    2/2-3
    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.
    2/2-3
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    SG 8252 - 258 SP 301
    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.
    Saga Petroleum ASA
    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.
    362-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.
    97
    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,
    04.02.1983
    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.
    11.05.1983
    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.
    11.05.1985
    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.
    27.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    65.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4100.0
    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).
    4096.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    8
    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.
    TRIASSIC
    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.
    SMITH BANK FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    56° 47' 36.42'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    3° 25' 38.14'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6294616.14
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    526100.02
    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.
    3
  • Wellbore history

    General
    The wildcat 2/2-3 was drilled on a domal structure, south of the Ula-Gyda fault zone. Main objective was Late Jurassic sandstone in the Vestland Group. Secondary target was Middle Jurassic and Late Triassic sandstones.
    According to the license agreement the well should be drilled into the Triassic, salt, or a maximum depth of 5000 m whatever came first
    Operations and results
    The well was spudded with the semi-submersible rig Treasure Saga on 4 February 1983 and drilled to TD at 4100 m, 170 m into the Triassic Smith Bank Formation. At 3286 m the string was lost after a wiper trip. The well had to be plugged back to 3053 m and sidetracked from this point. At 3420 m the string was again lost but was recovered. The well was drilled using water-based mud. The well was drilled with seawater and bentonite down to 655 m, with polymer/gypsum/"SST 202" mud from 655 m to 1910 m, with lignite/Drispac/gypsum mud from 1910 m to 3523 m, and with lignite/lignosulphonate mud from 3523 m to TD.
    The well penetrated 2998 m of Cenozoic sediments represented by the Nordland, Hordaland and Rogaland Groups. The sequence was mainly composed of argillaceous deposits. The Oligocene Sand Unit (Vade Formation) recognized in well 2/2-1 and 2/2-2, was not established in this well. The Cretaceous sequence consisted of two lithostratgraphic units, the Chalk and Cromer Knoll Group. They were separated by an unconformity ranging from Santonian to Middle Albian. The Early Cretaceous and upper part of the Late Jurassic (Ryazanian-Middle Volgian) are highly condensed. The Late Jurassic predominantly consists of claystones of the Mandal (4m) and Farsund Formations. The Ula Formation is present from 3880 m in the bottom part of the Late Jurassic as a sandstone sequence of Early Kimmeridgian - Late Oxfordian age. The formation is resting unconformably on sediments of the Triassic Group.
    The Shetland Group chalk, 2965 m to 3494 m, has 112 meters of net porous limestone with an average porosity of 21 percent. The chalk is clean. Where the porosity is highest, 3050 m to 3090 m, the well has a large wash-out. The Ula Formation was a sandstone with 19 percent mean porosity (based on core and log analyses), but with a permeability not exceeding 1 mD in any net sand found. The cored sand was well cemented. The Triassic formation that was penetrated, 3930 m to 4100 m, had 15 meters of sand with a porosity of 16 percent. The sand was more shaly than the Jurassic sand. Fifty attempts were made to get formation pressures with the FMT-tool. Because of tight formation, only one measurement (4084.5 m in the Triassic sand with 10237 psi) can be assumed correct, and even this point was of questionable quality. All porous intervals in the well were water bearing. No shows were reported from this well. One core was cut from 3887.7 m to 3905.5 m in the Ula Formation sand. No fluid sample was acquired. The well was permanently abandoned as dry on 11 May 1983.
    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]
    220.00
    4100.00
  • 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
    1
    3887.7
    3905.0
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    17.3
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES
  • Core photos

    Core photos
    Core photo at depth: 3887-3894m
    Core photo at depth: 3894-3901m
    Core photo at depth: 3901-3905m
    Core photo at depth:  
    Core photo at depth:  
    3887-3894m
    3894-3901m
    3901-3905m
  • Palynological slides at the Norwegian Offshore Directorate

    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    4035.5
    [m]
    SWC
    OD
    4079.0
    [m]
    SWC
    OD
    4088.0
    [m]
    SWC
    OD
  • Lithostratigraphy

  • Composite logs

    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.54
  • 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
    20.97
  • Logs

    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CDL CNL GR
    1882
    3522
    CDL CNL GR SPECTRALOG
    3517
    4099
    DIFL BHC GR
    214
    654
    DIFL BHC GR
    640
    1911
    DIFL BHC GR
    1850
    3522
    DIFL BHC GR
    3485
    4101
    DIPLOG
    3516
    4101
    FMT
    3511
    0
    FMT
    4084
    0
    SWC
    2185
    3013
    SWC
    3571
    4088
    VSP
    100
    4085
  • 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
    214.0
    36
    215.0
    0.00
    LOT
    SURF.COND.
    20
    650.0
    26
    655.0
    1.39
    LOT
    INTERM.
    13 3/8
    1897.0
    17 1/2
    1910.0
    1.93
    LOT
    INTERM.
    9 5/8
    3516.0
    12 1/4
    3523.0
    2.14
    LOT
    OPEN HOLE
    4100.0
    8 1/2
    4100.0
    0.00
    LOT
  • Drilling mud

    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    450
    1.10
    50.0
    water
    900
    1.11
    51.0
    water
    1130
    1.16
    51.0
    water
    1320
    1.23
    60.0
    water
    1630
    1.27
    25.0
    water
    1920
    1.36
    49.0
    water
    2080
    1.36
    59.0
    water
    2440
    1.44
    50.0
    water
    2630
    1.47
    52.0
    water
    2720
    1.56
    52.0
    water
    2830
    1.62
    57.0
    water
    3300
    1.70
    50.0
    water
    3450
    1.64
    45.0
    water
    4000
    1.68
    51.0
    water
    4100
    1.66
    51.0
    water
  • Pressure plots

    Pressure plots
    The pore pressure data is sourced from well logs if no other source is specified. In some wells where pore pressure logs do not exist, information from Drill stem tests and kicks have been used. The data has been reported to the NPD, and further processed and quality controlled by IHS Markit.
    Pressure plots
    Document name
    Document format
    Document size [MB]
    pdf
    0.22