Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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12.11.2024 - 01:25
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6407/12-2

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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.
    6407/12-2
    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.
    NORWEGIAN SEA
    Well name
    Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    6407/12-2
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    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.
    GDF SUEZ E&P 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.
    1270-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.
    28
    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,
    23.11.2009
    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.
    20.12.2009
    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.
    03.10.2011
    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.
    03.10.2011
    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.
    40.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    308.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    1481.5
    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).
    1481.5
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    1
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    48
    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.
    EARLY CRETACEOUS
    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.
    LANGE FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    64° 9' 40.44'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    7° 48' 27.87'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7115699.99
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    442019.97
    UTM zone
    Universal Transverse Mercator zone. Examples of legal values: 31, 32, 33, 34.
    32
    NPDID wellbore
    Norwegian Offshore Directorate's unique id for the wellbore.
    6191

  • Wellbore history
    General
    Well 6407/12-2 was drilled south of the Draugen Field, in the Froan Basin in the Norwegian Sea. The main objective was to examine the reservoir potential of the base Eocene to Late Paleocene. Two targets were identified, the primary being the Tare Formation consisting of sands or tuffs at approximately 1029 m. The secondary target of the lower Brygge Formation consisting of sand should occur at approximately 999 m.
    Operations and results
    Wildcat well 6407/12-2 was spudded with the semi-submersible installation Aker Barents on 23 November 2009 and drilled to TD at 1482 m in the Late Cretaceous Lange Formation. A pilot hole was drilled from TD in 36" section at 430.5 m to 765 m to check for possible shallow gas at 527 and 584 m. No shallow gas was detected. The well was drilled with seawater and hi-vis bentonite mud pills down to 765 m and with Glydril WBM from 765 m to TD.
    The Tare Formation (base of Brygge Formation) was encountered at 1030 m. The two target reservoirs were both less in magnitude and quality than prognosed, and LWD/MWD logs proved them to be water bearing. No oil shows were observed in the well.
    One core was cut from 1035 m to 1051.5 m in the Tare Formation with 84.5% recovery. The MDT tool was run and attempted to take 14 pressure points, of which only three points in the Brygge Formation were valid. No fluid sample was taken.
    The well was permanently abandoned on 20 December 2009 as a dry well.
    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]
    770.00
    1481.50

  • 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
    1035.0
    1049.0
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    14.0
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1010.0
    [m]
    DC
    GDF
    1013.0
    [unknown]
    DC
    GDF
    1016.0
    [unknown]
    DC
    GDF
    1019.0
    [unknown]
    DC
    GDF
    1022.0
    [unknown]
    DC
    GDF
    1025.0
    [unknown]
    DC
    GDF
    1028.0
    [unknown]
    DC
    GDF
    1031.0
    [unknown]
    DC
    GDF
    1034.0
    [unknown]
    DC
    GDF
    1035.8
    [unknown]
    C
    GDF
    1036.8
    [unknown]
    C
    GDF
    1038.3
    [unknown]
    C
    GDF
    1040.2
    [unknown]
    C
    GDF
    1042.0
    [unknown]
    C
    GDF
    1044.3
    [unknown]
    C
    GDF
    1046.2
    [unknown]
    C
    GDF
    1048.2
    [unknown]
    C
    GDF
    1163.0
    [unknown]
    DC
    GDF
    1172.0
    [unknown]
    DC
    GDF
    1178.0
    [unknown]
    DC
    GDF
    1193.0
    [unknown]
    DC
    GDF
    1211.0
    [unknown]
    DC
    GDF
    1220.0
    [unknown]
    DC
    GDF
    1229.0
    [unknown]
    DC
    GDF
    1240.0
    [unknown]
    DC
    GDF
    1280.0
    [unknown]
    DC
    GDF
    1330.0
    [unknown]
    DC
    GDF
    1340.0
    [unknown]
    DC
    GDF
    1350.0
    [unknown]
    DC
    GDF
    1380.0
    [unknown]
    DC
    GDF
    1410.0
    [unknown]
    DC
    GDF
    1430.0
    [unknown]
    DC
    GDF
    1440.0
    [unknown]
    DC
    GDF
    1450.0
    [unknown]
    DC
    GDF
    1460.0
    [unknown]
    DC
    GDF

  • Lithostratigraphy
    Lithostratigraphy
    Top depth [mMD RKB]
    Lithostrat. unit
    348
    348
    422
    580
    580
    1030
    1030
    1239
    1421
    1421

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.25

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    txt
    0.00
    txt
    0.03

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    DSI HRLA PEX ECS HNGS
    964
    1482
    LWD - ARC8
    426
    765
    LWD - ARC8 SON VIS8 SADN8
    426
    765
    LWD - ARC8 SON VIS8 SADN8
    765
    968
    LWD - GEO VIS ARC VIS
    0
    0
    MDT GR
    1001
    1051
    VSP GR
    484
    1476

  • 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
    426.0
    36
    430.0
    0.00
    LOT
    SURF.COND.
    13 3/8
    759.0
    17 1/2
    765.0
    1.54
    LOT
    INTERM.
    9 5/8
    967.0
    12 1/4
    968.0
    1.72
    LOT
    OPEN HOLE
    1481.5
    8 1/2
    1481.5
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    0
    1.02
    Bentonite spud mud.
    700
    1.40
    25.0
    K+/Glycol inhibitive WBM
    968
    1.25
    18.0
    K+/Glycol inhibitive WBM
    1051
    1.40
    19.0
    K+/Glycol inhibitive WBM
    1275
    1.41
    25.0
    K+/Glycol inhibitive WBM
    1481
    1.40
    23.0
    K+/Glycol inhibitive WBM

  • Thin sections at the Norwegian Offshore Directorate
    Thin sections at the Norwegian Offshore Directorate
    Depth
    Unit
    1004.00
    [m ]
    1109.00
    [m ]
    1118.00
    [m ]
    1034.00
    [m ]
    1030.00
    [m ]
    1007.00
    [m ]
    995.00
    [m ]
    1001.00
    [m ]
    998.00
    [m ]
    1124.00
    [m ]
    1035.03
    [m ]
    1036.03
    [m ]
    1041.50
    [m ]
    1118.00
    [m ]