Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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01.11.2024 - 01:26
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6407/9-8

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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.
    6407/9-8
    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.
    RE-CLASS TO DEV
    Multilateral
    Indicator telling if the parent well is multilateral, meaning it has more than one branch radiating from the main borehole. Example of legal values: YES, NO. See also Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    NO
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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.
    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.
    6407/9-8
    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.
    A/S Norske Shell
    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.
    739-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.
    40
    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,
    14.08.1992
    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.
    22.09.1992
    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.
    22.09.1994
    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.
    28.06.2007
    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
    Reclassified to wellbore
    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.
    22.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    230.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2126.0
    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).
    2125.4
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    65
    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 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.
    TILJE FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    64° 23' 7.69'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    7° 57' 37.47'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7140556.61
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    449852.14
    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.
    1974

  • Wellbore history
    General
    Wildcat well 6407/9-8 was drilled on the Husmus East structure, situated east of the Draugen Field on the edge of the Trøndelag Platform on the Mid Norwegian Continental Shelf. The principal objective of the well was to test the hydrocarbon potential of the Late Jurassic Rogn Formation in a dip closure trap. Secondary objective was to test the potential for gas storage in the Rogn Formation and in the middle Jurassic Garn Formation. The well was also drilled to acquire additional stratigraphic information on the reservoir development of the Middle and Early Jurassic Ile and Tilje Formation.
    Operations and results
    Well 6407/9-8 was spudded with the semi-submersible installation West Vanguard on 14 August 1992 and drilled to TD at 2126 m in the Early Jurassic Tilje Formation. Operations went without significant problems. The well was drilled with seawater and bentonite down to 1120 m, with polymer/gypsum mud from 1120 m to 1582 m, and with KCl/polymer mud from 1582 m to TD.
    No potential reservoir zones were found above the Viking Group, which was penetrated from 1606.5 m to 1730 m. The Rogn Formation vas poorly developed as a thin (<1 m), well-cemented silty to very fine sandstone facies with low porosity and permeability. A well-developed Garn Formation in a sand facies vas encountered, with high porosities and permeabilities. The well vas terminated in sandstone of the Tilje Formation after penetration of Ile Formation sandstone. Both the Garn Formation and the Ile Formations appeared to be suitable for gas injection. The well was entirely water wet all through. This was evident from electrical logs, pressure gradients, and lack of shows on cores and cuttings. Post-well geochemical analyses of cores and cuttings confirmed general lack of migrated hydrocarbons. A total of seven cores were cut in the well with 105.95 m recovered. Cores 1 to 5 were cut from 1605 m to 1685 m in the Spekk and Rogn Formations. Cores 6 and 7 were cut from 1723 m to 1760.5 m in the Melke and Garn Formations. A dense FMT pressure-sampling programme confirmed a water-wet reservoir with a pressure gradient close to the theoretical gradient for the established Draugen Formation water. A number of attempts were made to take water samples at depths of 1731.5 m (Garn) and 1940 m (Ile). Some degree of filtrate contamination vas noted.
    The well was classified as dry and was suspended on 23 September 1992 as a possible future development well for the Draugen Field. It was re-entered on 14 August and taken in use as a gas injector
    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]
    1130.00
    2127.00

  • 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
    1605.0
    1622.1
    [m ]
    2
    1623.0
    1633.1
    [m ]
    3
    1633.5
    1642.0
    [m ]
    4
    1650.0
    1666.0
    [m ]
    5
    1666.0
    1685.0
    [m ]
    6
    1723.0
    1741.9
    [m ]
    7
    1742.0
    1758.7
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    106.2
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 1605-1609m
    Core photo at depth: 1609-1613m
    Core photo at depth: 1613-1617m
    Core photo at depth: 1617-1621m
    Core photo at depth: 1621-1622m
    1605-1609m
    1609-1613m
    1613-1617m
    1617-1621m
    1621-1622m
    Core photo at depth: 1623-1627m
    Core photo at depth: 1627-1631m
    Core photo at depth: 1631-1633m
    Core photo at depth: 1633-1637m
    Core photo at depth: 1637-1641m
    1623-1627m
    1627-1631m
    1631-1633m
    1633-1637m
    1637-1641m
    Core photo at depth: 1641-1642m
    Core photo at depth: 1650-1654m
    Core photo at depth: 1654-1658m
    Core photo at depth: 1658-1662m
    Core photo at depth: 1662-1666m
    1641-1642m
    1650-1654m
    1654-1658m
    1658-1662m
    1662-1666m
    Core photo at depth: 1666-1670m
    Core photo at depth: 1670-1674m
    Core photo at depth: 1674-1678m
    Core photo at depth: 1678-1682m
    Core photo at depth: 1682-1684m
    1666-1670m
    1670-1674m
    1674-1678m
    1678-1682m
    1682-1684m
    Core photo at depth: 1723-1727m
    Core photo at depth: 1727-1731m
    Core photo at depth: 1731-1735m
    Core photo at depth: 1735-1739m
    Core photo at depth: 1739-1741m
    1723-1727m
    1727-1731m
    1731-1735m
    1735-1739m
    1739-1741m
    Core photo at depth: 1742-1746m
    Core photo at depth: 1746-1750m
    Core photo at depth: 1750-1754m
    Core photo at depth: 1754-1758m
    Core photo at depth: 1758-1759m
    1742-1746m
    1746-1750m
    1750-1754m
    1754-1758m
    1758-1759m

  • 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
    309.7
    36
    310.0
    0.00
    LOT
    INTERM.
    18 5/8
    1110.0
    26
    1112.0
    0.00
    LOT
    INTERM.
    13 3/8
    1553.3
    17 1/2
    1555.0
    1.62
    LOT
    INTERM.
    9 5/8
    2118.0
    12 1/4
    2120.0
    1.73
    LOT

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CORGUN
    286
    400
    CORGUN
    286
    400
    CORGUN
    1134
    1578
    CORGUN
    1550
    2110
    CORGUN
    1688
    1852
    CORGUN
    1860
    1933
    CORGUN
    1939
    2098
    DIFL ACL BHC GR
    1110
    1582
    DIFL BHC ACL GR
    252
    1113
    DIFL BHC ACL GR
    252
    1113
    DIFL BHC ACL GR
    1110
    1582
    DIFL BHC ACL GR
    1553
    1759
    DIFL BHC ACL GR
    1553
    2120
    DIPLOG
    1550
    2110
    DLL MLL GR
    1553
    2115
    FMT
    1651
    1920
    FMT
    1731
    2096
    FMT
    1880
    2105
    FMT
    1940
    1940
    MWD
    252
    160
    SBT VDL GR
    1419
    2086
    SPECTRALOG
    1553
    2120
    VSP
    1553
    2121
    ZDL CNL GR
    252
    1113
    ZDL CNL GR
    252
    1113
    ZDL CNL GR
    1110
    1582
    ZDL CNL GR
    1553
    1759
    ZDL CNL GR
    1553
    2120
    ZDL FDC GR
    1110
    1582

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.48

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    4.38

  • 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
    43.91

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    310
    1.02
    200.0
    WATER BASED
    316
    1.01
    200.0
    WATER BASED
    477
    1.02
    200.0
    WATER BASED
    674
    1.02
    200.0
    WATER BASED
    1117
    1.02
    200.0
    WATER BASED
    1117
    1.02
    200.0
    WATER BASED
    1120
    1.02
    200.0
    WATER BASED
    1125
    1.39
    60.0
    WATER BASED
    1400
    1.39
    60.0
    WATER BASED
    1582
    1.39
    82.0
    WATER BASED
    1598
    1.13
    37.0
    WATER BASED
    1650
    1.14
    39.0
    WATER BASED
    1666
    1.14
    40.0
    WATER BASED
    1702
    1.15
    40.0
    WATER BASED
    1742
    1.15
    39.0
    WATER BASED
    1800
    1.16
    39.0
    WATER BASED
    1962
    1.14
    38.0
    WATER BCSED
    2126
    1.14
    38.0
    WATER BASED