Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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19.07.2024 - 01:27
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25/11-25 S

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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.
    25/11-25 S
    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
    Press release
    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.
    25/11-25
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    NH9301- inline 1660 & crossline 2020
    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.
    StatoilHydro Petroleum 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.
    1159-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.
    27
    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,
    20.01.2008
    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.
    15.02.2008
    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.
    15.02.2010
    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.
    15.02.2010
    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.
    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
    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.
    YES
    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.
    26.0
    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).
    2142.0
    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).
    1830.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    54.7
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    77
    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.
    LISTA FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    59° 8' 48.64'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 23' 21.12'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6556714.79
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    465056.23
    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.
    5642
  • Wellbore history

    General
    Well 25/11-5 S and the geological sidetrack 25/11-25 A are located in a petroleum system just south of the Balder Field and southwest of the Grane Field, on the western margin of the Utsira High. The primary objective of the wells was to prove commercial hydrocarbons in the two independent prospects; M-prospect and Jacob North prospect (1500m apart). In 25/11-25 S the primary objective was to confirm producible oil from Intra Balder Formation Sandstone ("Odin sands"). A secondary objective was to evaluate the shallower Frigg sand and the Hermod Formation sandstones.
    The objective of the 25/11-25 A sidetrack was to evaluate the formations within the Jurassic Statfjord Formation. The discovery of a 4 meter oil column in the Statfjord Formation in the recently drilled Jakob Sør prospect by well 25/11-24
    necessitated an evaluation of potential Statfjord Formation targets in the area. The Jakob Nord and Jakob Sør prospects were separated by a saddle point coinciding with the oil water contact encountered in well 25/11-24.
    Operations and results
    Wildcat well 25/11-25 S was spudded with the semi-submersible installation Transocean Winner on 20 January 2008 and drilled to TD at 2142 m in the Paleocene Lista Formation. No shallow gas was observed by the ROV at the wellhead or by the MWD while drilling the 36" hole and the 12 1/4" pilot hole. The well was drilled with seawater down to 1094 m, and with Glydril mud (with ca 4% glycol) from 1094 m to TD.
    The well penetrated rocks of Quaternary and Tertiary age. No Frigg sand was encountered and no recordable sand volumes were present in the Sele Formation. The well penetrated the Odin reservoir section at 2045 m, 14.4 m deeper than prognosed. Wire line logs confirmed an oil bearing interval between 2045 m and 2082.5 m proving oil down to the OWC at 2082.5 m (1790m TVD RKB). No shows were observed in the well other than in the oil-bearing Intra Balder Formation sandstone.
    The well track was plugged back to 1476 m and permanently abandoned on 15 February 2008 as an oil discovery.
    Well 25/11-25 A was sidetracked from 25/11-25 S at 1023 m and drilled to a total depth of 2448 m (2058 m TVD RKB). The well was drilled with Glydril mud (with ca 4% glycol) from kick-off to TD.
    The well penetrated rocks of Tertiary, Cretaceous and Jurassic age. TD of the well was set in sandstones and claystones of the Statfjord Formation. The Statfjord Formation in well 25/11-25 A was encountered at 2372 m, 12 m TVD deeper than prognosed. The reservoir was more poorly developed than expected and there were no indications of hydrocarbons. Biostratigraphic results indicated presence of the lowermost part of the Lower Statfjord Formation only. No shows were reported in well 25/11-25 A.
    One core was cut in 25/11-25 S in a hydrocarbon bearing interval from 2045 m - 2063 m the Intra Balder Formation sandstone, with 93% recovery. No cores were cut in 25/11-25 A. MDT oil sampling was performed at 2046 m and at 2065 m in 25/11-25 S. In total 175.7 litres were pumped during the sampling run of which 94.9 litres were pumped to the well bore. No fluid sampling was done in 25/11-25 A.
    Sidetrack well 25/11-25 A was permanently abandoned on 10 March 2008 as dry well.
    Testing
    No drill stem test was performed in the wells.
    p>
  • 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]
    1100.00
    2143.00
  • 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
    2045.0
    2061.7
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    16.7
    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
    1130.0
    [m]
    DC
    FUGRO
    1140.0
    [m]
    DC
    FUGRO
    1150.0
    [m]
    DC
    FUGRO
    1168.0
    [m]
    DC
    FUGRO
    1180.0
    [m]
    DC
    FUGRO
    1190.0
    [m]
    DC
    FUGRO
    1200.0
    [m]
    DC
    FUGRO
    1210.0
    [m]
    DC
    FUGRO
    1220.0
    [m]
    DC
    FUGRO
    1230.0
    [m]
    DC
    FUGRO
    1240.0
    [m]
    DC
    FUGRO
    1250.0
    [m]
    DC
    FUGRO
    1260.0
    [m]
    DC
    FUGRO
    1270.0
    [m]
    DC
    FUGRO
    1280.0
    [m]
    DC
    FUGRO
    1290.0
    [m]
    DC
    FUGRO
    1300.0
    [m]
    DC
    FUGRO
    1310.0
    [m]
    DC
    FUGRO
    1320.0
    [m]
    DC
    FUGRO
    1330.0
    [m]
    DC
    FUGRO
    1340.0
    [m]
    DC
    FUGRO
    1350.0
    [m]
    DC
    FUGRO
    1360.0
    [m]
    DC
    FUGRO
    1370.0
    [m]
    DC
    FUGRO
    1380.0
    [m]
    DC
    FUGRO
    1390.0
    [m]
    DC
    FUGRO
    1400.0
    [m]
    DC
    FUGRO
    1410.0
    [m]
    DC
    FUGRO
    1420.0
    [m]
    DC
    FUGRO
    1430.0
    [m]
    DC
    FUGRO
    1440.0
    [m]
    DC
    FUGRO
    1450.0
    [m]
    DC
    FUGRO
    1460.0
    [m]
    DC
    FUGRO
    1470.0
    [m]
    DC
    FUGRO
    1480.0
    [m]
    DC
    FUGRO
    1490.0
    [m]
    DC
    FUGRO
    1500.0
    [m]
    DC
    FUGRO
    1510.0
    [m]
    DC
    FUGRO
    1520.0
    [m]
    DC
    FUGRO
    1530.0
    [m]
    DC
    FUGRO
    1540.0
    [m]
    DC
    FUGRO
    1560.0
    [m]
    DC
    FUGRO
    1570.0
    [m]
    DC
    FUGRO
    1580.0
    [m]
    DC
    FUGRO
    1590.0
    [m]
    DC
    FUGRO
    1600.0
    [m]
    DC
    FUGRO
    1610.0
    [m]
    DC
    FUGRO
    1620.0
    [m]
    DC
    FUGRO
    1630.0
    [m]
    DC
    FUGRO
    1640.0
    [m]
    DC
    FUGRO
    1650.0
    [m]
    DC
    FUGRO
    1660.0
    [m]
    DC
    FUGRO
    1670.0
    [m]
    DC
    FUGRO
    1680.0
    [m]
    DC
    FUGRO
    1690.0
    [m]
    DC
    FUGRO
    1700.0
    [m]
    DC
    FUGRO
    1710.0
    [m]
    DC
    FUGRO
    1720.0
    [m]
    DC
    FUGRO
    1730.0
    [m]
    DC
    FUGRO
    1740.0
    [m]
    DC
    FUGRO
    1750.0
    [m]
    DC
    FUGRO
    1760.0
    [m]
    DC
    FUGRO
    1770.0
    [m]
    DC
    FUGRO
    1780.0
    [m]
    DC
    FUGRO
    1790.0
    [m]
    DC
    FUGRO
    1800.0
    [m]
    DC
    FUGRO
    1810.0
    [m]
    DC
    FUGRO
    1820.0
    [m]
    DC
    FUGRO
    1830.0
    [m]
    DC
    FUGRO
    1840.0
    [m]
    DC
    FUGRO
    1850.0
    [m]
    DC
    FUGRO
    1860.0
    [m]
    DC
    FUGRO
    1870.0
    [m]
    DC
    FUGRO
    1880.0
    [m]
    DC
    FUGRO
    1890.0
    [m]
    DC
    FUGRO
    1900.0
    [m]
    DC
    FUGRO
    1910.0
    [m]
    DC
    FUGRO
    1920.0
    [m]
    DC
    FUGRO
    1930.0
    [m]
    DC
    FUGRO
    1939.0
    [m]
    DC
    FUGRO
    1942.0
    [m]
    DC
    FUGRO
    1945.0
    [m]
    DC
    FUGRO
    1948.0
    [m]
    DC
    FUGRO
    1951.0
    [m]
    DC
    FUGRO
    1954.0
    [m]
    DC
    FUGRO
    1957.0
    [m]
    DC
    FUGRO
    1960.0
    [m]
    DC
    FUGRO
    1963.0
    [m]
    DC
    FUGRO
    1966.0
    [m]
    DC
    FUGRO
    1969.0
    [m]
    DC
    FUGRO
    1972.0
    [m]
    DC
    FUGRO
    1975.0
    [m]
    DC
    FUGRO
    1978.0
    [m]
    DC
    FUGRO
    1981.0
    [m]
    DC
    FUGRO
    1984.0
    [m]
    DC
    FUGRO
    1987.0
    [m]
    DC
    FUGRO
    1990.0
    [m]
    DC
    FUGRO
    1993.0
    [m]
    DC
    FUGRO
    1996.0
    [m]
    DC
    FUGRO
    1999.0
    [m]
    DC
    FUGRO
    2002.0
    [m]
    DC
    FUGRO
    2005.0
    [m]
    DC
    FUGRO
    2008.0
    [m]
    DC
    FUGRO
    2011.0
    [m]
    DC
    FUGRO
    2014.0
    [m]
    DC
    FUGRO
    2017.0
    [m]
    DC
    FUGRO
    2020.0
    [m]
    DC
    FUGRO
    2023.0
    [m]
    DC
    FUGRO
    2026.0
    [m]
    DC
    FUGRO
    2029.0
    [m]
    DC
    FUGRO
    2032.0
    [m]
    DC
    FUGRO
    2035.0
    [m]
    DC
    FUGRO
    2038.0
    [m]
    DC
    FUGRO
    2041.0
    [m]
    DC
    FUGRO
    2045.1
    [m]
    C
    FUGRO
    2045.3
    [m]
    C
    FUGRO
    2047.5
    [m]
    C
    FUGRO
    2047.7
    [m]
    C
    FUGRO
    2048.0
    [m]
    C
    FUGRO
    2048.5
    [m]
    C
    FUGRO
    2068.0
    [m]
    DC
    FUGRO
    2071.0
    [m]
    DC
    FUGRO
    2074.0
    [m]
    DC
    FUGRO
    2077.0
    [m]
    DC
    FUGRO
    2080.0
    [m]
    DC
    FUGRO
  • 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
    MDT
    0.00
    0.00
    OIL
    YES
  • Lithostratigraphy

  • Logs

    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    MWD - DIR
    151
    208
    MWD - EWR P4 DGR PWD
    806
    2142
    MWD - EWR P4D DGR PWD
    208
    806
    MWD - EWR P4D DGR PWR
    208
    840
  • 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
    204.0
    36
    204.0
    0.00
    LOT
    SURF.COND.
    13 3/8
    1087.0
    17 1/2
    1094.0
    1.69
    LOT
    LINER
    9 5/8
    1934.0
    12 1/4
    1936.0
    1.72
    LOT
    OPEN HOLE
    2142.0
    8 1/2
    2142.0
    0.00
    LOT
  • Drilling mud

    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    1132
    1.30
    GLYDRIL
    1168
    1.32
    31.0
    GLYDRIL
    1299
    1.33
    30.0
    GLYDRIL
    1500
    1.45
    34.0
    GLYDRIL
    1936
    1.47
    31.0
    GLYDRIL
    2045
    1.26
    23.0
    GLYDRIL
    2084
    1.26
    26.0
    GLYDRIL
    2142
    1.26
    26.0
    GLYDRIL
  • 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
    0.21