Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
22.12.2024 - 01:25
Time of last synchronization with Norwegian Offshore Directorate's internal systems

25/7-6

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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.
    25/7-6
    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
    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
    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
    Field
    Name of the field the wellbore is related to.
    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.
    25/7-6
    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.
    Norsk Hydro Produksjon 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.
    982-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.
    32
    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,
    13.09.2000
    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.
    14.10.2000
    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.
    14.10.2002
    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.
    15.02.2006
    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
    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.
    26.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    124.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2250.0
    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).
    2250.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    1.4
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    71
    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.
    PALEOCENE
    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.
    HEIMDAL FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    59° 29' 15.04'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 0' 37.34'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6594908.84
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    443947.92
    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.
    4141

  • Wellbore history
    General
    Well 25/7-6 was drilled to appraise the Kobra oil discovery made by well 25/7-5 in 1997. The main objectives of the well were to prove sufficient volumes to be able to initiate an oil development, and to identify an oil-water contact in an at least 20 m thick Hermod T80 sand member of the Sele Formation.
    Operations and results
    Wildcat well 25/7-6 was spudded with the semi-submersible installation Scarabeo 6 on 13 September 2000 and drilled to TD at 2250 m, 100 m into the Paleocene Heimdal Formation. Problems with the hole packing of in the section from 226 m to ca 790 m caused some delay and problems with setting the 13 3/8" casing. Otherwise no significant drilling problems were encountered. The well was drilled with spud mud down to 1345 m and with Glydril mud from 1345 m to TD.
    Thirteen m of water bearing Hermod T80 sandstone was encountered at 2069 m. The sandstone had no residual hydrocarbons, but oil shows were recorded on the core from the same interval. The Heimdal Formation was encountered at 2149.5 and was also water wet according to logs and the MDT pressure gradient
    One core was cut from 2061 m to 2079.65 m in the Sele/Hermod Formation. No fluid samples were taken in the well.
    The well was permanently abandoned on 14 October 2000 as a well with shows.
    Testing
    No drill stem test was performed in the well.

  • 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]
    1350.00
    2250.00

  • 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
    2061.0
    2079.7
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    18.7
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 2061-2065m
    Core photo at depth: 2065-2069m
    Core photo at depth: 2069-2073m
    Core photo at depth: 2073-2077m
    Core photo at depth: 2077-2079m
    2061-2065m
    2065-2069m
    2069-2073m
    2073-2077m
    2077-2079m

  • 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
    223.0
    36
    225.0
    1.60
    LOT
    SURF.COND.
    13 3/8
    1331.0
    17 1/2
    1345.0
    1.65
    LOT
    INTERM.
    9 5/8
    1884.0
    12 1/4
    1891.0
    0.00
    LOT
    OPEN HOLE
    2250.0
    8 1/2
    2250.0
    0.00
    LOT

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    MDT GR
    2270
    2237
    MWD CDR - GR RES DIR
    150
    2246
    PEX DSI
    1400
    2237
    VSI GR
    1400
    2230

  • Lithostratigraphy
    Lithostratigraphy
    Top depth [mMD RKB]
    Lithostrat. unit
    150
    447
    717
    1203
    1305
    1931
    1931
    2042
    2069
    2082
    2103
    2150

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.21

  • 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
    2.36
    .PDF
    4.61

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    1345
    1.45
    26.0
    WATER BASED
    1891
    1.50
    27.0
    WATER BASED
    2006
    1.20
    13.0
    WATER BASED
    2070
    1.20
    15.0
    WATER BASED
    2210
    1.20
    15.0
    WATER BASED
    2250
    1.20
    14.0
    WATER BASED

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1350.0
    [m]
    DC
    RRI
    1370.0
    [m]
    DC
    RRI
    1390.0
    [m]
    DC
    RRI
    1410.0
    [m]
    DC
    RRI
    1430.0
    [m]
    DC
    RRI
    1450.0
    [m]
    DC
    RRI
    1470.0
    [m]
    DC
    RRI
    1490.0
    [m]
    DC
    RRI
    1510.0
    [m]
    DC
    RRI
    1530.0
    [m]
    DC
    RRI
    1550.0
    [m]
    DC
    RRI
    1570.0
    [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
    1840.0
    [m]
    DC
    RRI
    1870.0
    [m]
    DC
    RRI
    1891.0
    [m]
    DC
    RRI
    1900.0
    [m]
    DC
    RRI
    1910.0
    [m]
    DC
    RRI
    1920.0
    [m]
    DC
    RRI
    1930.0
    [m]
    DC
    RRI
    1940.0
    [m]
    DC
    RRI
    1950.0
    [m]
    DC
    RRI
    1960.0
    [m]
    DC
    RRI
    1970.0
    [m]
    DC
    RRI
    1982.0
    [m]
    DC
    RRI
    1995.0
    [m]
    DC
    RRI
    2005.0
    [m]
    DC
    RRI
    2010.0
    [m]
    DC
    RRI
    2017.0
    [m]
    DC
    RRI
    2022.0
    [m]
    DC
    RRI
    2030.0
    [m]
    DC
    RRI
    2035.0
    [m]
    DC
    RRI
    2040.0
    [m]
    DC
    RRI
    2045.0
    [m]
    DC
    RRI
    2050.0
    [m]
    DC
    RRI
    2055.0
    [m]
    DC
    RRI
    2060.0
    [m]
    DC
    RRI
    2061.0
    [m]
    C
    RRI
    2062.0
    [m]
    C
    RRI
    2063.0
    [m]
    C
    RRI
    2064.0
    [m]
    C
    RRI
    2065.0
    [m]
    C
    RRI
    2066.0
    [m]
    C
    RRI
    2067.0
    [m]
    C
    RRI
    2068.0
    [m]
    C
    RRI
    2082.0
    [m]
    DC
    RRI
    2087.0
    [m]
    DC
    RRI
    2090.0
    [m]
    DC
    RRI
    2095.0
    [m]
    DC
    RRI
    2100.0
    [m]
    DC
    RRI
    2105.0
    [m]
    DC
    RRI
    2110.0
    [m]
    DC
    RRI
    2115.0
    [m]
    DC
    RRI
    2120.0
    [m]
    DC
    RRI
    2130.0
    [m]
    DC
    RRI
    2140.0
    [m]
    DC
    RRI
    2150.0
    [m]
    DC
    RRI
    2160.0
    [m]
    DC
    RRI
    2170.0
    [m]
    DC
    RRI
    2180.0
    [m]
    DC
    RRI
    2190.0
    [m]
    DC
    RRI
    2200.0
    [m]
    DC
    RRI
    2210.0
    [m]
    DC
    RRI
    2220.0
    [m]
    DC
    RRI
    2230.0
    [m]
    DC
    RRI
    2240.0
    [m]
    DC
    RRI
    2250.0
    [m]
    DC
    RRI