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

25/11-7

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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.
    25/11-7
    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.
    25/11-7
    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.
    Esso Exploration and Production Norway 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.
    204-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.
    25
    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,
    03.10.1978
    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.
    27.10.1978
    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.
    27.10.1980
    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.
    30.04.2010
    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
    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
    1st level with HC, age
    Age of lithostratigraphic unit, 1st level, where hydrocarbons were encountered. Examples of legal values: CRETACEOUS, EARLY CRETACEOUS, LATE JURASSIC, EOCENE. See also Norwegian Offshore Directorate bulletins.
    EOCENE
    1st level with HC, formation
    Name of lithostartigraphic unit, 1st level, where hydrocarbons were encountered. Shown only for released wells. Examples of legal values: BASEMENT, COOK FM, EKOFISK FM, HEIMDAL FM, SANDNES FM, SOGNEFJORD FM, TARBERT FM, BRENT GP. See also Norwegian Offshore Directorate bulletins.
    INTRA BALDER FM SS
    2nd level with HC, age
    Age of lithostratigraphic unit, 2nd level, where hydrocarbons were encountered. Examples of legal values: CRETACEOUS, EARLY CRETACEOUS, LATE JURASSIC, EOCENE.
    PALEOCENE
    2nd level with HC, formation
    Name of lithostartigraphic unit, 2nd level, where hydrocarbons were encountered. Shown only for released wells. Examples of legal values: BASEMENT, COOK FM, EKOFISK FM, HEIMDAL FM, SANDNES FM, SOGNEFJORD FM, TARBERT FM, BRENT GP.
    HEIMDAL FM
    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.
    124.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    1944.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    1
    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 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.
    TOR FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    59° 10' 33.07'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 21' 47.23'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6559958.95
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    463595.03
    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.
    368

  • Wellbore history
    General
    Well 25/11-7 was drilled ca 3 km west-south west of the 25/11-1 Balder discovery well on the Utsira High in the North Sea. The primary objective was to delineate topographic mounds developed in the Paleocene sands of the Balder Field. The primary targets were the Zone II sand (E-70 sand) which was found oil-bearing in the 25/11-5 and the Zone I-B sands which were found oil-bearing in the 25/11-6.
    Operations and results
    Appraisal well 25/11-7 was spudded with the semi-submersible installation Norskald on 3 October 1978 and drilled to TD at 1944 m in the Late Cretaceous Tor Formation. The well was drilled with Seawater/Gel/Lignosulphonate.
    The well penetrated the Utsira Formation and several Skade Formation sands and then penetrated a ca 600 m thick section of shales belonging to the lower Hordaland Group before top Balder Formation was encountered at 1697 m. The Balder Formation contained some shaley sands with poor to no oil shows. The massive I-B sand at 1750.3 m (Heimdal Formation) was the only significant oil sand in the well. The well proved 36 m of net oil sand with a clear oil-water contact at 1786.5 m (1761.5 m MSL), in reasonable agreement with the Balder Field contact at 1760 m MSL established in 25/11-6. The Zone II (E-70) sand was absent, or possibly an unrecognizable part of the I-B Sand.
    A total of 20.35 m core was recovered in four cores from the interval 1748.6 to 1772.3 m in the Lista and Heimdal Formations. No wire line fluid samples were taken.
    The well was permanently abandoned on 27 October 1978 as an oil appraisal 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]
    1070.00
    1945.30

  • 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
    1748.6
    1751.0
    [m ]
    2
    1751.0
    1753.0
    [m ]
    3
    1753.0
    1762.4
    [m ]
    4
    1762.4
    1772.3
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    23.7
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • 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
    186.0
    36
    186.0
    0.00
    LOT
    INTERM.
    13 3/8
    396.0
    17 1/2
    412.0
    0.00
    LOT
    INTERM.
    9 5/8
    1308.0
    12 1/4
    1325.0
    0.00
    LOT
    OPEN HOLE
    1944.0
    8 1/2
    1944.0
    0.00
    LOT

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CAL
    1311
    1845
    DLL MSFL
    1500
    1945
    FDC CNL
    1500
    1945
    GR
    149
    410
    HDT
    1500
    1945
    ISF SONIC
    184
    410
    ISF SONIC
    396
    1316
    ISF SONIC
    1311
    1944
    VELOCITY
    930
    1945

  • Lithostratigraphy

  • 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
    1.28
    pdf
    100.03

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    186
    0.00
    waterbased
    694
    1.08
    waterbased
    1325
    1.06
    waterbased
    1531
    1.11
    waterbased
    1944
    1.13
    waterbased

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1090.0
    [m]
    DC
    CGG
    1110.0
    [m]
    DC
    CGG
    1150.0
    [m]
    DC
    CGG
    1190.0
    [m]
    DC
    CGG
    1220.0
    [m]
    DC
    CGG
    1300.0
    [m]
    DC
    CGG
    1350.0
    [m]
    DC
    CGG
    1360.0
    [m]
    DC
    CGG
    1370.0
    [m]
    DC
    CGG
    1380.0
    [m]
    DC
    CGG
    1400.0
    [m]
    DC
    CGG
    1430.0
    [m]
    DC
    CGG
    1440.0
    [m]
    DC
    CGG
    1450.0
    [m]
    DC
    CGG
    1460.0
    [m]
    DC
    CGG
    1470.0
    [m]
    DC
    CGG
    1480.0
    [m]
    DC
    CGG
    1490.0
    [m]
    DC
    CGG
    1560.0
    [m]
    DC
    CGG
    1580.0
    [m]
    DC
    CGG
    1600.0
    [m]
    DC
    1625.0
    [m]
    SWC
    1630.0
    [m]
    DC
    1638.0
    [m]
    SWC
    1652.0
    [m]
    SWC
    1655.0
    [m]
    DC
    CGG
    1659.0
    [m]
    SWC
    1665.0
    [m]
    DC
    1665.0
    [m]
    DC
    CGG
    1670.0
    [m]
    DC
    CGG
    1675.0
    [m]
    DC
    CGG
    1675.0
    [m]
    SWC
    1680.0
    [m]
    DC
    CGG
    1686.0
    [m]
    SWC
    1690.0
    [m]
    DC
    CGG
    1695.0
    [m]
    DC
    1698.0
    [m]
    SWC
    1700.0
    [m]
    DC
    CGG
    1705.0
    [m]
    DC
    CGG
    1705.0
    [m]
    DC
    CGG
    1710.0
    [m]
    DC
    CGG
    1715.0
    [m]
    DC
    CGG
    1717.0
    [m]
    SWC
    1720.0
    [m]
    DC
    CGG
    1725.0
    [m]
    DC
    1727.0
    [m]
    SWC
    1730.0
    [m]
    DC
    CGG
    1734.0
    [m]
    SWC
    1740.0
    [m]
    DC
    CGG
    1743.0
    [m]
    SWC
    1748.8
    [m]
    C
    1749.0
    [m]
    C
    1749.0
    [m]
    SWC
    1782.0
    [m]
    SWC
    1785.0
    [m]
    DC
    1803.0
    [m]
    SWC
    1815.0
    [m]
    DC
    1825.0
    [m]
    DC
    CGG
    1829.0
    [m]
    SWC
    1835.0
    [m]
    DC
    CGG
    1845.0
    [m]
    C
    1845.5
    [m]
    SWC
    1850.0
    [m]
    DC
    CGG
    1851.0
    [m]
    SWC
    1855.0
    [m]
    DC
    CGG
    1858.0
    [m]
    SWC
    1860.0
    [m]
    DC
    CGG
    1861.0
    [m]
    SWC
    1875.0
    [m]
    DC
    CGG
    1875.0
    [m]
    C
    1878.5
    [m]
    SWC
    1880.0
    [m]
    DC
    CGG
    1883.0
    [m]
    SWC
    1885.0
    [m]
    DC
    CGG
    1889.5
    [m]
    SWC
    1890.0
    [m]
    DC
    CGG
    1895.0
    [m]
    SWC
    1899.0
    [m]
    SWC
    1900.0
    [m]
    DC
    CGG
    1904.0
    [m]
    SWC
    1905.0
    [m]
    DC
    1908.0
    [m]
    SWC
    1914.0
    [m]
    SWC
    1918.0
    [m]
    SWC
    1920.0
    [m]
    DC
    CGG
    1925.0
    [m]
    DC
    1930.0
    [m]
    DC
    1940.0
    [m]
    SWC
    1945.3
    [m]
    C
    10000.0
    [m]
    C