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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6204/11-2

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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.
    6204/11-2
    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
    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.
    6204/11-2
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    ST 9202-INLINE 263 & X-LINE 404
    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.
    915-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.
    23
    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,
    06.12.1997
    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.
    28.12.1997
    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.
    28.12.1999
    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.
    17.12.2003
    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.
    25.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    197.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2920.0
    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).
    2919.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    2.5
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    85
    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.
    SOGNEFJORD FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    62° 11' 50.47'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    4° 26' 37.67'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6897169.35
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    575131.87
    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.
    3249

  • Wellbore history
    General
    Well 6204/11-2 is located in the eastern part of the Slørebotn sub-basin, ca 3 km east-northeast of well 6204/11-1. Well 6204/11-1 proved shows in the Cretaceous Lysing Formation Equivalent and made a sub-commercial gas discovery in the Middle Jurassic. The objectives of well 6204/11-2 were to prove hydrocarbon reserves in the I-prospect, in a Coniacian/Turonian Sandstone and in the O-prospect, an Albian/Aptian Rødby Sandstone
    Operations and results
    Exploration well 6204/11-2 was spudded with the semi-submersible installation Deepsea Trym on 6 December 1997 and drilled to TD at 2920 m in the Late Jurassic Sognefjord Formation. The well was drilled with seawater and PAC sweeps to 1352 m and with PAC / KCl mud from 1352 m to TD.
    The 6204/11-2 well proved no hydrocarbons in the I- and O-prospects. This has been deduced by FMT sampling and petrophysical evaluation of wire line logs. The O-prospect was prognosed to be sandy, but a conglomerate was encountered. Gas readings were low throughout the well. The highest readings were in the claystones above the Lysing Formation Equivalent, ranging from less than 0.1 % to 0.6%. Traces of fluorescence were reported at several intervals throughout the well below 1984 m. Only in the Sognefjord Formation (2892 m to TD) moderate direct fluorescence were observed, but the poor cut fluorescence compared with the moderate direct fluorescence indicates residual HC only, in accordance with the wire line logs. FMT fluid samples were taken at 1992.3 m and at 2893.0 m. Both 10 l chambers were drained off shore and were observed to contained mud filtrate and formation water. Oil film was observed in the sample at 1992.3 m, but analysis showed that it was from a base oil, either due to lack of cleaning of the FMT chamber prior to use or due to trace of base oil in the mud used in the well. No cores were taken. The well was permanently abandoned as a dry well with shows on December 28t 1997.
    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]
    1360.00
    2920.00

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1360.0
    [m]
    DC
    RRI
    1380.0
    [m]
    DC
    RRI
    1400.0
    [m]
    DC
    RRI
    1420.0
    [m]
    DC
    RRI
    1440.0
    [m]
    DC
    RRI
    1460.0
    [m]
    DC
    RRI
    1480.0
    [m]
    DC
    RRI
    1500.0
    [m]
    DC
    RRI
    1520.0
    [m]
    DC
    RRI
    1540.0
    [m]
    DC
    RRI
    1560.0
    [m]
    DC
    RRI
    1590.0
    [m]
    DC
    RRI
    1600.0
    [m]
    DC
    RRI
    1620.0
    [m]
    DC
    RRI
    1640.0
    [m]
    DC
    RRI
    1660.0
    [m]
    DC
    RRI
    1680.0
    [m]
    DC
    RRI
    1700.0
    [m]
    DC
    RRI
    1720.0
    [m]
    DC
    RRI
    1740.0
    [m]
    DC
    RRI
    1760.0
    [m]
    DC
    RRI
    1780.0
    [m]
    DC
    RRI
    1800.0
    [m]
    DC
    RRI
    1820.0
    [m]
    DC
    RRI
    1850.0
    [m]
    DC
    RRI
    1870.0
    [m]
    DC
    RRI
    1900.0
    [m]
    DC
    RRI
    1912.0
    [m]
    DC
    RRI
    1924.0
    [m]
    DC
    RRI
    1942.0
    [m]
    DC
    RRI
    1948.0
    [m]
    DC
    RRI
    1966.0
    [m]
    DC
    RRI
    1972.0
    [m]
    DC
    RRI
    1978.0
    [m]
    DC
    RRI
    2005.0
    [m]
    DC
    RRI
    2013.0
    [m]
    DC
    RRI
    2017.0
    [m]
    DC
    RRI
    2023.0
    [m]
    DC
    RRI
    2035.0
    [m]
    DC
    RRI
    2041.0
    [m]
    DC
    RRI
    2047.0
    [m]
    DC
    RRI
    2053.0
    [m]
    DC
    RRI
    2059.0
    [m]
    DC
    RRI
    2076.0
    [m]
    DC
    RRI
    2095.0
    [m]
    DC
    RRI
    2128.0
    [m]
    DC
    RRI
    2164.0
    [m]
    DC
    RRI
    2200.0
    [m]
    DC
    RRI
    2218.0
    [m]
    DC
    RRI
    2236.0
    [m]
    DC
    RRI
    2272.0
    [m]
    DC
    RRI
    2290.0
    [m]
    DC
    RRI
    2308.0
    [m]
    DC
    RRI
    2326.0
    [m]
    DC
    RRI
    2365.0
    [m]
    DC
    RRI
    2380.0
    [m]
    DC
    RRI
    2392.0
    [m]
    DC
    RRI
    2404.0
    [m]
    DC
    RRI
    2422.0
    [m]
    DC
    RRI
    2437.0
    [m]
    DC
    RRI
    2452.0
    [m]
    DC
    RRI
    2467.0
    [m]
    DC
    RRI
    2482.0
    [m]
    DC
    RRI
    2497.0
    [m]
    DC
    RRI
    2512.0
    [m]
    DC
    RRI
    2526.0
    [m]
    DC
    RRI
    2542.0
    [m]
    DC
    RRI
    2560.0
    [m]
    DC
    RRI
    2573.0
    [m]
    DC
    RRI
    2617.0
    [m]
    DC
    RRI
    2632.0
    [m]
    DC
    RRI
    2647.0
    [m]
    DC
    RRI
    2659.0
    [m]
    DC
    RRI
    2686.0
    [m]
    DC
    RRI
    2709.0
    [m]
    DC
    RRI
    2716.0
    [m]
    DC
    RRI
    2722.0
    [m]
    DC
    RRI
    2728.0
    [m]
    DC
    RRI
    2734.0
    [m]
    DC
    RRI
    2740.0
    [m]
    DC
    RRI
    2752.0
    [m]
    DC
    RRI
    2758.0
    [m]
    DC
    RRI
    2779.0
    [m]
    DC
    RRI
    2788.0
    [m]
    DC
    RRI
    2797.0
    [m]
    DC
    RRI
    2815.0
    [m]
    DC
    RRI
    2824.0
    [m]
    DC
    RRI
    2833.0
    [m]
    DC
    RRI
    2842.0
    [m]
    DC
    RRI
    2851.0
    [m]
    DC
    RRI
    2860.0
    [m]
    DC
    RRI
    2869.0
    [m]
    DC
    RRI
    2878.0
    [m]
    DC
    RRI
    2896.0
    [m]
    DC
    RRI
    2914.0
    [m]
    DC
    RRI
    2920.0
    [m]
    DC
    RRI

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.44

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    1.91
    pdf
    1.54

  • 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
    24.89

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    DLL MLL ZDL GR TTRM
    1343
    2917
    FMT GR
    1908
    2910
    FMT GR
    2893
    2893
    MAC DSL TTRM
    1019
    2917
    MWD - DPR
    1358
    2911
    MWD - RNT
    282
    1058
    SWC GR
    1830
    2905
    VSP GR
    473
    2898

  • 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
    282.0
    36
    285.0
    0.00
    LOT
    SURF.COND.
    9 5/8
    1344.0
    12 1/4
    1346.0
    1.59
    LOT
    OPEN HOLE
    2920.0
    8 1/2
    2920.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    0
    0.00
    DUMMY
    248
    1.04
    DUMMY
    978
    1.04
    SEAWATER/PAC
    1352
    1.04
    SEAWATER/PAC
    1843
    1.25
    16.0
    KCL/GLYCOL/POLY
    2188
    1.25
    16.0
    KCL/GLYCOL/POLY
    2354
    1.25
    15.0
    KCL/GLYCOL/POLY
    2715
    1.25
    18.0
    KCL/GLYCOL/POLY
    2743
    1.25
    16.0
    KCL/GLYCOL/POLY
    2808
    1.25
    18.0
    KCL/GLYCOL/POLY
    2920
    1.25
    19.0
    KCL/GLYCOL/POLY

  • 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
    0.26