Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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34/4-13 S

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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.
    34/4-13 S
    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).
    APPRAISAL
    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
    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.
    34/4-13
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    PCR06M01-inline 1959 & crossline 1707
    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.
    Petro-Canada Norge 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.
    1323-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.
    129
    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,
    27.08.2010
    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.
    02.01.2011
    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.
    02.01.2013
    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.
    15.01.2013
    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.
    APPRAISAL
    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.
    OIL
    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
    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.
    EARLY 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.
    STATFJORD GP
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    18.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    374.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    5010.0
    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).
    4291.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    37.5
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    151
    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 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.
    LUNDE FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    61° 38' 42.96'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 6' 0.2'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6835156.57
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    452314.90
    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.
    6442

  • Wellbore history
    General
    The exploration well Beta Statfjord 34/4-13 S was drilled on the Tampen Spur area in the northern North Sea to appraise the Beta Brent Discovery made by well 34/4-11 in 2009. The primary objective was to evaluate oil and or gas in sandstones of the Cook and Statfjord formations and Hegre Group. The original plan was a vertical well, but to meet the time slot available for the rig a site survey over the proposed target location was unable to be completed. Hence a deviated well from the ready surveyed 34/4-11 location was decided.
    Operations and results
    Appraisal well 34/4-13 S was spudded with the semi-submersible installation West Alpha on 27 August 2010 and drilled to TD at 5010 m (4291 m TVD) in the Late Triassic Lunde Formation. The well was drilled directionally (J-shaped well) with a sail angle through the 17 1/2", 12 1/4" and 8 1/2" intervals of approximately 37 deg. Significant downtime with the BOP system was incurred prior to and during running the BOP. Otherwise no significant technical problems were encountered in the operations. The well was drilled with sea water and hi-vis pills down to 1480 m, with Versatec OBM from 1480 m to 4382 m, and with Versatherm OBM from 4382 m to TD.
    Top Viking Group was penetrated at 4422 m, the Brent Group came in at 4499 m, and top Dunlin Group at 4525 m. The Brent and Dunlin groups were dominantly mudstones without hydrocarbons except from a silty interval from 4686 to 4710 m that had traces of sand with oil shows. The Statfjord Formation was encountered at 4800 m (4122 m TVD) and had a good quality porous hydrocarbon bearing sandstone interval at the top of the zone from 4801 to 4816.5 m and a smaller porous sandstone interval at 4841.5 m to 4845 m. Core and well log data supported an oil-down-to depth of 4847 m (4160 m TVD). However two additional porous sandstone units identified on logs lower down in the Statfjord Formation at 4871 m to 4872.3 m and 4893 m to 4895.4 m would suggest a potential oil-down-to depth of 4894.3 m (4197 m TVD). There was no oil/water contact identified on the well logs. Oil shows were recorded on core no 4 down to a depth of 4902 m. There were no shows discernible from the OBM below this depth or above 4686 m.
    A total of 68.3 m core was recovered in three cores from 4801 to 4849.5 m and a fourth core from 4894 to 4916 m. MDT fluid samples were taken at 4805.1 m (oil with ca 9% mud filtrate) and at 4814.8 m (oil with ca 3% mud filtrate). Single stage separation of the samples, corrected for contamination, gave a GOR of ca 150 Sm3/Sm3, a stock tank gravity of ca 0.823 g/cm3, and a gas gravity of 0.955 (air = 1).
    The well was permanently abandoned on 2 January 2011 as an oil appraisal well.
    Testing
    One drill stem test was conducted from perforations at 4803 - 4815 m (4107 - 4116 m TVD) in the Statfjord Formation sandstone. The main flow produced 1399 Sm3 oil and ca 127000 Sm3 gas /day through a 34/64" choke with no signs of decline of the oil or gas rate. The GOR was ca 93 Sm3/Sm3. All flows were water free, with 3 ppm of H2S and CO2 of about 2% in the gas stream. Bottom hole temperature in the test was 144.8 deg C.

  • 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]
    1490.00
    5010.00

  • 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
    4801.0
    4826.9
    [m ]
    2
    4828.0
    4834.6
    [m ]
    3
    4835.0
    4849.0
    [m ]
    4
    4894.0
    4915.9
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    68.4
    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
    DST
    4813.71
    4803.00
    OIL
    12.12.2010 - 23:05
    YES

  • Lithostratigraphy

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    4803
    4815
    13.6
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    73.800
    74.900
    115
    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
    1400

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    AIT GPIT PPC DSI PPC PEX
    2900
    4380
    AIT PEX HNGS
    4375
    5007
    CBL
    2902
    4335
    CMR XPT
    4490
    5005
    DOBMI GPIT PPC DSI PPC GR
    2850
    5007
    DSLT GR CCL
    4228
    4943
    MDT
    4801
    4981
    MSCT
    4496
    4801
    MWD - GR RES PWD DI
    392
    1480
    MWD - PDGR GR RES PWD DI SON
    1480
    5010
    PMIT CCL
    390
    4334
    USIT DSLT GR CCL
    4228
    4920
    VSP
    640
    4995

  • 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
    470.0
    36
    471.0
    0.00
    LOT
    PILOT HOLE
    600.0
    9 7/8
    600.0
    0.00
    LOT
    SURF.COND.
    20
    1472.6
    26
    1480.0
    0.00
    LOT
    SURF.COND.
    13 3/8
    2903.0
    17 1/2
    2908.0
    1.86
    LOT
    INTERM.
    9 5/8
    4376.0
    12 1/4
    4382.0
    2.20
    LOT
    LINER
    7
    5009.0
    8 1/2
    5010.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    415
    1.02
    40.0
    cmc
    474
    1.49
    27.0
    bentonite spud
    600
    1.02
    50.0
    bentonite spud
    1480
    1.24
    22.0
    bentonite spud
    1633
    1.50
    46.0
    Versatec
    2908
    1.53
    46.0
    Versatec
    2993
    1.66
    52.0
    Versatec
    3556
    1.71
    56.0
    Versatec
    4004
    0.99
    51.0
    Versatec
    4330
    0.99
    50.0
    Versatec
    4382
    1.73
    53.0
    Versatec
    4383
    1.71
    51.0
    Versatec
    4525
    2.03
    64.0
    Versatherm
    4802
    1.99
    68.0
    Versatherm
    4829
    1.99
    72.0
    Versatherm
    4915
    1.99
    72.0
    Versatherm
    5007
    1.99
    71.0
    versatherm
    5007
    1.73
    36.0
    versatherm
    5007
    1.70
    CaBr2 Brine
    5007
    1.70
    CaBr2 Brine
    5010
    1.99
    71.0
    Versatherm
    5010
    2.09
    73.0
    Versatherm
    5010
    1.99
    69.0
    Versatherm

  • Thin sections at the Norwegian Offshore Directorate
    Thin sections at the Norwegian Offshore Directorate
    Depth
    Unit
    4915.60
    [m ]
    4900.95
    [m ]
    4845.24
    [m ]
    4841.50
    [m ]
    4811.88
    [m ]
    4808.25
    [m ]
    4804.67
    [m ]
    4801.83
    [m ]