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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2/4-21

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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.
    2/4-21
    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
    Press release
    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.
    2/4-21
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    VGCNSO5R07NH-inline 7862 & trace 18770
    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.
    Statoil Petroleum AS
    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.
    1382-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.
    127
    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,
    19.01.2012
    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.
    24.05.2012
    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.
    24.05.2014
    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.
    24.05.2014
    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/CONDENSATE
    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.
    LATE JURASSIC
    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.
    FARSUND FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    48.1
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    67.4
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    5395.0
    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).
    5392.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    7.6
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    183
    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 JURASSIC
    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.
    FARSUND FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    56° 42' 0.81'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    3° 8' 34.31'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6284166.46
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    508748.77
    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.
    6736

  • Wellbore history
    General
    Well 2/4-21 was drilled on the King Lear prospect in the Central Graben of the Norwegian North Sea, approximately 20 km north of the Ekofisk Field. The prospect was considered a part of the same reservoir as in the 2/4-14 well that ultimately ended up in a major underground blowout in 1989. The main objective of the well was to prove commercial hydrocarbons in intra-Farsund Formation sandstone units.
    Operations and results
    Well 2/4-21 was spudded with the jack-up installation Mærsk Gallant on 19 Jan.2012 and drilled to TD at 5395 m in the Late Jurassic Farsund Formation. No over-pressured shallow gas was seen, but a 2-3 m thick sand at 627 m contained normal-pressured gas with a composition consistent with a biogenic origin. The well was planned as an HPHT well with pressure prognosis based on results from the 2/4-18 well. Pressures proved to be even higher than prognosed and at 5029 m influx of gas occurred. The well was shut in and after several days control operations the mud was weighted up to 2.1 g/cm3 and drilling continued to TD. Well 2/4-21 was plugged back after having reached TD. All data acquisition was carried out in the main track, but it was decided to drill a parallel vertical sidetrack (2/4-21 T2) for the purpose of achieving good cores from the main reservoir level (the Farsund II sandstone). The sidetrack was kicked off successfully at 4933m and the operations were carried out according to plan. The well was drilled with sea water/spud mud down to 248 m, with spud mud/KCl/Polymer mud from 248 to 453 m, with KCl/polymer/GEM mud from 453 to 1019 m, with oil based XP07-low ECD mud from 1019 m to 3022 m, and with oil based XP07-HPHT mud from 3022 m to TD. Oil based XP07-HPHT mud was used also in the coring side track.
    Top Mandal Formation was encountered at 4767 m and top Farsund Formation at 4795 m. A main Intra Farsund Formation sandstone was penetrated as prognosed from 5122 to 5173 m. This interval had 23 m good quality reservoir sand with 21% porosity and 13 mD permeability. It contained rich gas-condensate in a gas-down-to situation. The pressure survey indicated pressure depletion compared to thin sandstones above and below the main reservoir due to the underground blow-out in well 2/4-14. Prognosed sandstone units below this level proved to be thin cemented sandstone and limestone stringers. No fluorescent shows are described from the cuttings in the Farsund II unit / main reservoir. Descriptions from the sidewall cores indicate oil stain and hydrocarbon odour on samples as shallow as 4996 m and tar filled voids down to 5182 m.
    One core was cut in the Farsund Formation in the primary well bore from 5069 m to 5083. 5 m. Two further cores were cut in the Farsund Formation in the 2/4-21 T2 sidetrack from 5116 m to 5166 m. Wire line fluid samples were taken at 5053.5 m (oil and gas; considered as the best sample with only 2.3% mud contamination), 5122.5 m (oil and gas; medium quality sample), and 5167.5 m (oil and gas). PVT analyses of the samples showed a GOR in the range 1200 - 1400 Sm3/Sm3.
    The well was permanently abandoned on 24 May 2012 as a gas-condensate discovery.
    Testing
    No drill stem test was performed.
    l>

  • 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]
    260.00
    5394.00

  • 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
    5069.0
    5083.4
    [m ]
    2
    5116.0
    5136.9
    [m ]
    3
    5139.0
    5166.2
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    62.5
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Oil samples at the Norwegian Offshore Directorate
    Oil samples at the Norwegian Offshore Directorate
    Test type
    Bottle number
    Top depth
    MD [m]
    Bottom depth
    MD [m]
    Fluid type
    Test time
    Samples available
    MDT
    0.00
    5167.50
    CONDENSATE
    YES
    MDT
    0.00
    5121.50
    CONDENSATE
    YES
    MDT
    0.00
    5053.50
    CONDENSATE
    YES

  • Lithostratigraphy

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL GR
    3100
    4625
    CORGUN
    5068
    5083
    CTN ALD EWR P4 DGR PWD DIR FTWD
    5030
    5250
    DIR PWD
    253
    447
    EWR - P4 DGR DIR PWD
    253
    5030
    EWR P4 DEG GEOPILOT PWD
    1015
    3019
    GEOTAP GM EWR P4 PWD ALD CTN DIR
    5250
    5395
    HNGS AIT PEX
    4600
    5256
    MDT
    4994
    5243
    MDT
    5053
    5122
    MDT
    5167
    5167
    MSCT
    4995
    5245
    MWD
    115
    253
    OBMI IS MSIP GR
    3600
    5257
    VSI ZO
    2569
    5256
    XPT
    0
    0

  • 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
    240.0
    36
    248.0
    1.20
    FIT
    SURF.COND.
    20
    434.0
    26
    453.0
    1.40
    FIT
    PILOT HOLE
    447.0
    9 7/8
    447.0
    0.00
    INTERM.
    16
    1005.0
    20
    1019.0
    1.68
    FIT
    INTERM.
    14
    3003.0
    17 1/2
    3022.0
    1.90
    FIT
    INTERM.
    9 7/8
    4638.0
    12 1/4
    4649.0
    2.16
    FIT
    OPEN HOLE
    5395.0
    8 1/2
    5573.0
    0.00

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    248
    1.10
    33.0
    KCl/Polymer
    447
    1.20
    15.0
    KCl/Polymer/GEM
    447
    1.13
    16.0
    KCl/Polymer
    652
    1.16
    15.0
    KCl/Polymer/GEM
    1015
    1.22
    16.0
    KCl/Polymer/GEM
    1244
    1.45
    19.0
    OBM-Low ECD
    2320
    1.60
    21.0
    OBM-Low ECD
    3019
    1.60
    23.0
    OBM-Low ECD
    3414
    1.61
    28.0
    OBM-Low ECD
    4140
    1.61
    28.0
    OBM-Low ECD
    4513
    1.74
    32.0
    OBM-Low ECD-HTHP
    4646
    2.04
    43.0
    OBM-Low ECD-HTHP
    4646
    1.78
    36.0
    OBM-Low ECD-HTHP
    4646
    1.76
    34.0
    OBM-Low ECD
    4649
    2.08
    77.0
    OBM-Low ECD-HTHP
    4840
    2.04
    41.0
    OBM-Low ECD-HTHP
    4932
    2.08
    64.0
    OBM-Low ECD-HTHP
    5013
    2.04
    45.0
    OBM-Low ECD-HTHP
    5029
    2.08
    54.0
    OBM-Low ECD-HTHP
    5029
    2.09
    51.0
    OBM-Low ECD-HTHP
    5029
    2.09
    52.0
    OBM-Low ECD-HTHP
    5063
    2.08
    58.0
    OBM-Low ECD-HTHP
    5083
    2.08
    56.0
    OBM-Low ECD-HTHP
    5115
    2.08
    67.0
    OBM-Low ECD-HTHP
    5139
    2.08
    73.0
    OBM-Low ECD-HTHP
    5166
    2.08
    73.0
    OBM-Low ECD-HTHP
    5250
    2.10
    61.0
    OBM-Low ECD-HTHP
    5250
    2.10
    61.0
    OBM-Low ECD-HTHP
    5392
    2.08
    63.0
    OBM-Low ECD-HTHP
    5395
    2.08
    62.0
    OBM-Low ECD-HTHP