Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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05.11.2024 - 01:27
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6608/8-1

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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.
    6608/8-1
    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.
    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.
    6608/8-1
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    3D ST 9405 INLINE 1283& CROSSLINE 1000
    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.
    Den norske stats oljeselskap a.s
    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.
    873-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.
    58
    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,
    01.02.1997
    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.
    30.03.1997
    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.
    30.03.1999
    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.
    15.11.2001
    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.
    OIL SHOWS
    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.
    23.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    334.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3013.0
    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).
    3005.0
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    108
    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 PERMIAN
    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.
    ZECHSTEIN GP
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    66° 18' 32.69'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    8° 30' 58.84'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7354632.57
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    478313.59
    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.
    2974

  • Wellbore history
    General
    The main objective for the well was to test the hydrocarbon potential in the Permian carbonates, which was an unproven play type in this area. Secondary objectives were to test possible Pliocene Kai Formation sandstone near the prognosed pinch-out, possible Paleocene sandstone, Triassic sandstones, and Permian sandstone/weathered basement.
    Operations and results
    The well was drilled vertically using a water based mud to 3013 m RKB where massive losses occurred. It was not possible to stabilize the well, and it was plugged back permanently. The well was classified as a dry well. Traces of oil shows were however reported during drilling in the uppermost part of the Triassic succession. High gas readings that probably originated from TD were recorded during circulation to stabilize the well. Two cores were cut from 1833 to 1843 m RKB in Triassic and another two from 2766 to 2795 m in Permian. An FMT fluid sample from 1832 m RKB contained mainly mud filtrate and only trace hydrocarbon gases.
    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]
    670.00
    2999.00

  • 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
    1833.0
    1833.4
    [m ]
    2
    1834.0
    1842.8
    [m ]
    3
    2766.0
    2767.8
    [m ]
    4
    2768.0
    2774.8
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    17.8
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 1833-1834m
    Core photo at depth: 1834-1839m
    Core photo at depth: 1839-1842m
    Core photo at depth: 2766-2767m
    Core photo at depth: 2768-2773m
    1833-1834m
    1834-1839m
    1839-1842m
    2766-2767m
    2768-2773m
    Core photo at depth: 2773-2774m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    2773-2774m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    670.0
    [m]
    DC
    RRI
    700.0
    [m]
    DC
    RRI
    760.0
    [m]
    DC
    RRI
    800.0
    [m]
    DC
    RRI
    820.0
    [m]
    DC
    RRI
    850.0
    [m]
    DC
    RRI
    860.0
    [m]
    DC
    RRI
    890.0
    [m]
    DC
    RRI
    920.0
    [m]
    DC
    RRI
    950.0
    [m]
    DC
    RRI
    990.0
    [m]
    DC
    RRI
    1020.0
    [m]
    DC
    RRI
    1030.0
    [m]
    DC
    RRI
    1060.0
    [m]
    DC
    RRI
    1100.0
    [m]
    DC
    RRI
    1130.0
    [m]
    DC
    RRI
    1150.0
    [m]
    DC
    RRI
    1170.0
    [m]
    DC
    RRI
    1180.0
    [m]
    DC
    RRI
    1200.0
    [m]
    DC
    RRI
    1230.0
    [m]
    DC
    RRI
    1260.0
    [m]
    DC
    RRI
    1290.0
    [m]
    DC
    RRI
    1410.0
    [m]
    DC
    RRI
    1450.0
    [m]
    DC
    RRI
    1490.0
    [m]
    DC
    RRI
    1550.0
    [m]
    DC
    RRI
    1560.0
    [m]
    DC
    RRI
    1580.0
    [m]
    DC
    RRI
    1691.0
    [m]
    DC
    RRI
    1711.0
    [m]
    DC
    RRI
    1776.0
    [m]
    DC
    RRI
    1786.0
    [m]
    DC
    RRI
    1834.6
    [m]
    C
    WESTL
    1837.0
    [m]
    C
    WESTL
    1840.0
    [m]
    C
    WESTL
    1842.6
    [m]
    C
    WESTL
    1885.0
    [m]
    DC
    RRI
    1895.0
    [m]
    DC
    RRI
    1955.0
    [m]
    DC
    RRI
    2465.0
    [m]
    DC
    RRI
    2474.0
    [m]
    DC
    RRI
    2483.0
    [m]
    DC
    RRI
    2492.0
    [m]
    DC
    RRI
    2501.0
    [m]
    DC
    RRI
    2510.0
    [m]
    DC
    RRI
    2519.0
    [m]
    DC
    RRI
    2528.0
    [m]
    DC
    RRI
    2549.0
    [m]
    DC
    RRI
    2558.0
    [m]
    DC
    RRI
    2567.0
    [m]
    DC
    RRI
    2576.0
    [m]
    DC
    RRI
    2585.0
    [m]
    DC
    RRI
    2766.2
    [m]
    C
    WESTL
    2768.6
    [m]
    C
    WESTL
    2770.8
    [m]
    C
    WESTL
    2772.7
    [m]
    C
    WESTL
    2774.5
    [m]
    C
    WESTL

  • Lithostratigraphy
    Lithostratigraphy
    Top depth [mMD RKB]
    Lithostrat. unit
    357
    357
    1326
    1428
    1428
    1513
    1513
    1607
    1623
    1623
    1753
    2755

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.27

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    1.66

  • 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
    8.67
    pdf
    58.16

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    DLL MLL MAC DSL CHT
    357
    1550
    DLL MLL MAC DSL CHT
    1475
    2560
    DPR
    358
    3013
    FMT GR
    1600
    2395
    SWC
    652
    1550
    SWC GR
    1567
    2560
    VSP GR
    1000
    2380
    ZDL CND DSL CHT
    652
    1550
    ZDL CND DSL CHT
    1544
    2560

  • 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
    418.0
    36
    418.0
    0.00
    LOT
    SURF.COND.
    20
    652.0
    26
    659.0
    1.39
    LOT
    INTERM.
    13 3/8
    1544.0
    17 1/2
    1624.0
    1.72
    LOT
    LINER
    9 5/8
    2585.0
    12 1/4
    2587.0
    1.71
    LOT
    OPEN HOLE
    3013.0
    8 1/2
    3013.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    957
    1.20
    WATER BASED
    1222
    1.03
    WATER BASED
    2337
    1.30
    23.0
    WATER BASED
    2667
    1.34
    24.0
    WATER BASED
    2785
    1.34
    22.0
    WATER BASED
    2900
    1.34
    21.0
    WATER BASED

  • 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
    0.28