Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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11.11.2024 - 01:26
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25/10-5

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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.
    25/10-5
    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
    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.
    25/10-5
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    BALMG 203 SP: 109.
    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.
    291-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.
    33
    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,
    15.06.1981
    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.
    17.07.1981
    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.
    17.07.1983
    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.
    07.11.2005
    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
    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
    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
    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.
    125.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2011.0
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    55
    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.
    VIKING GP
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    59° 10' 49.24'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 19' 26.97'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6560481.03
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    461373.07
    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.
    365

  • Wellbore history
    General
    The 25/10-5 well was drilled to establish the presence of an accumulation of Eocene oil sand in the western part of the Balder Field, and evaluate the geologic concept of sand-shale distribution and reservoir quality.
    Operations and results
    Wildcat well 25/10-5 was spudded with the semi-submersible installation Glomar Biscay II on 15 June 1981 and drilled to TD at 2011 m in the Late Jurassic Viking Group. The well was drilled with sea water/gel/lignosulphonate.
    The top of the Early Eocene reservoir was encountered at 1733 m (1708 m sub sea), as prognosed. The reservoir consisted of thin sandstone beds interbedded with shale and was oil bearing. A 49.5 m gross oil column was found down to an OWC at 1782.5 m. The net oil sandstone thickness was 18.2 m. Late Eocene Grid Formation sandstone was penetrated at 1398 m to 1443 m and Paleocene Heimdal Formation sandstone from 1905 m to 1929 m. These were both water wet without shows.
    Four cores were cut in the Lower Eocene reservoir sequence. No wire line test or fluid sampling was carried out.
    The well was permanently abandoned on 17 July 1981 as an oil appraisal well.
    Testing
    Two drill stem tests were performed in the Early Eocene reservoir. DST 1 perforated the interval 1756 m to 1753 m and produced 171 Sm3 oil/day. The oil gravity was 25.3 deg API and the gas/oil ratio was 59 m3/m3. DST2 perforated the intervals 1732 - 1740 m and 1756 - 1763 m. It produced 515 Sm3 oil/day. The oil gravity in DST2 was 25.5 deg API and the gas/oil ratio was 59 m3/m3.

  • 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]
    240.00
    2011.00

  • 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
    1739.0
    1742.9
    [m ]
    2
    1776.7
    1777.7
    [m ]
    3
    1781.0
    1781.9
    [m ]
    4
    1785.2
    1792.8
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    13.3
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1150.0
    [m]
    DC
    1180.0
    [m]
    DC
    1210.0
    [m]
    DC
    1240.0
    [m]
    DC
    1280.0
    [m]
    DC
    1310.0
    [m]
    DC
    1340.0
    [m]
    DC
    1380.0
    [m]
    DC
    1397.5
    [m]
    SWC
    1430.0
    [m]
    DC
    1443.5
    [m]
    SWC
    1470.0
    [m]
    DC
    1490.0
    [m]
    DC
    1520.0
    [m]
    DC
    1550.0
    [m]
    DC
    1580.0
    [m]
    DC
    1600.0
    [m]
    DC
    1630.0
    [m]
    DC
    1660.0
    [m]
    DC
    1690.0
    [m]
    DC
    1720.0
    [m]
    DC
    1735.4
    [m]
    SWC
    1741.4
    [m]
    C
    1742.5
    [m]
    C
    1746.0
    [m]
    SWC
    1749.5
    [m]
    SWC
    1750.0
    [m]
    DC
    1752.0
    [m]
    SWC
    1765.5
    [m]
    SWC
    1766.6
    [m]
    SWC
    1771.0
    [m]
    SWC
    1779.5
    [m]
    SWC
    1785.0
    [m]
    SWC
    1788.3
    [m]
    C
    1795.6
    [m]
    SWC
    1802.5
    [m]
    SWC
    1807.2
    [m]
    SWC
    1812.2
    [m]
    SWC
    1818.5
    [m]
    SWC
    1820.5
    [m]
    SWC
    1824.0
    [m]
    SWC
    1827.5
    [m]
    SWC
    1839.5
    [m]
    SWC
    1850.0
    [m]
    SWC
    1851.5
    [m]
    SWC
    1858.5
    [m]
    SWC
    1877.0
    [m]
    SWC
    1891.0
    [m]
    SWC
    1903.7
    [m]
    SWC
    1946.0
    [m]
    SWC
    1949.0
    [m]
    SWC
    1955.5
    [m]
    SWC
    1958.0
    [m]
    SWC
    1967.0
    [m]
    SWC
    1976.0
    [m]
    SWC

  • Oil samples at the Norwegian Offshore Directorate
    Oil samples at the Norwegian Offshore Directorate
    Test type
    Bottle number
    Top depth
    MD [m]
    Bottom depth
    MD [m]
    Fluid type
    Test time
    Samples available
    DST
    DST1
    1740.00
    1732.00
    11.07.1981 - 00:00
    YES
    DST
    DST2
    1763.00
    1756.00
    12.07.1981 - 00:00
    YES

  • 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
    5.78
    pdf
    4.68
    pdf
    1.10
    pdf
    47.70
    pdf
    27.12
    pdf
    6.63
    pdf
    11.02
    pdf
    11.77
    pdf
    1.27

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    1756
    1763
    12.7
    2.0
    1732
    1740
    25.4
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    2.0
    Drill stem tests (DST)
    Test number
    Oil
    [Sm3/day]
    Gas
    [Sm3/day]
    Oil density
    [g/cm3]
    Gas grav. rel.air
    GOR
    [m3/m3]
    1.0
    170
    10000
    0.900
    0.640
    59
    2.0
    515
    30000
    0.900
    0.640
    59

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CDL CNL
    1340
    2008
    CDM AP
    1340
    2008
    DLL MLL GR
    1700
    2008
    IEL BHC ACL GR SP
    145
    2007
    SWC
    1397
    2007
    VELOCITY
    145
    2007

  • 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
    211.0
    36
    211.0
    0.00
    LOT
    INTERM.
    13 3/8
    484.5
    17 1/2
    500.0
    1.75
    LOT
    INTERM.
    9 5/8
    1345.0
    12 1/4
    1370.0
    1.90
    LOT
    LINER
    7
    1991.0
    8 1/2
    2011.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    500
    1.07
    seawater
    1220
    1.08
    seawater
    1656
    1.17
    seawater
    2011
    1.25
    seawater