Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
25.11.2024 - 01:30
Time of last synchronization with Norwegian Offshore Directorate's internal systems

25/11-28

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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.
    25/11-28
    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
    Well name
    Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    25/11-28
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    LN12M02R14-RAW-KPSDM-FULL.inline 4614.crossline 4597
    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.
    Statoil 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.
    1597-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.
    19
    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,
    07.09.2015
    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.
    25.09.2015
    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.
    25.09.2017
    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.
    23.09.2017
    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.
    DRY
    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.
    118.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2590.0
    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).
    2588.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    7.9
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    102
    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.
    BASEMENT
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    59° 0' 31.12'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 21' 59.27'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6541337.87
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    463609.55
    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.
    7776

  • Wellbore history
    General
    Well 25/11-28 was drilled on the Utsira High ca 13 kilometres south of the Grane field in the North Sea. The objective of the well was to prove petroleum in Late Jurassic Intra Draupne Formation sandstone (Gasol prospect) and in the Permian Rotliegendes Group (Gretel prospect).
    Operations and results
    Wildcat well 25/11-28 was spudded with the semi-submersible installation Songa Trym on 7 September 2015 and drilled to TD at 2590 m in Basement rock. No significant problem was encountered in the operations. The well was drilled with seawater down to 565 m, with Glydril mud from 565 m to 1687 m and with EMS 4400 oil based mud from 1687 m to TD.
    The well encountered reservoir sandstones within the Viking Group, the Statfjord Group, the Triassic Hegre Group, and the Rotliegendes Group. The well penetrated basement rock (granite) at TD. Reservoir sandstones were found within the Draupne Formation, Statfjord Group and Hegre Group. All these reservoirs were water bearing. The Permian Rotliegendes Group, consisting of mainly conglomerates proved to be tight with poor reservoir quality. Pressure data showed two or three water gradients in the Statfjord Group. The lower pressured gradients were recorded in the upper part; above ca 2027 m, while the highest pressured Statfjord Gradient was below ca 2027 m. Moderate quality pressure points in the Intra Draupne sandstone and in the Hegre Group indicated higher pressures above and below the Statfjord Group. No oil shows were recorded in any section of the well.
    One core was cut from 1992 to 2046.6 m in the Intra Draupne Formation sandstone and in the Statfjord Group with 100% recovery. No fluid sample was taken.
    The well was permanently abandoned on 25 September as a dry 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]
    570.00
    2856.00

  • 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
    1992.0
    2046.6
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    54.6
    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
    570.0
    [m]
    DC
    CGG
    600.0
    [m]
    DC
    CGG
    630.0
    [m]
    DC
    CGG
    660.0
    [m]
    DC
    CGG
    690.0
    [m]
    DC
    CGG
    720.0
    [m]
    DC
    CGG
    810.0
    [m]
    DC
    CGG
    840.0
    [m]
    DC
    CGG
    900.0
    [m]
    DC
    CGG
    980.0
    [m]
    DC
    CGG
    1050.0
    [m]
    DC
    CGG
    1070.0
    [m]
    DC
    CGG
    1110.0
    [m]
    DC
    CGG
    1140.0
    [m]
    DC
    CGG
    1170.0
    [m]
    DC
    CGG
    1200.0
    [m]
    DC
    CGG
    1230.0
    [m]
    DC
    CGG
    1260.0
    [m]
    DC
    CGG
    1290.0
    [m]
    DC
    CGG
    1330.0
    [m]
    DC
    CGG
    1350.0
    [m]
    DC
    CGG
    1380.0
    [m]
    DC
    CGG
    1410.0
    [m]
    DC
    CGG
    1450.0
    [m]
    DC
    CGG
    1470.0
    [m]
    DC
    CGG
    1500.0
    [m]
    DC
    CGG
    1570.0
    [m]
    DC
    CGG
    1600.0
    [m]
    DC
    CGG
    1630.0
    [m]
    DC
    CGG
    1660.0
    [m]
    DC
    CGG
    1690.0
    [m]
    DC
    CGG
    1720.0
    [m]
    DC
    CGG
    1740.0
    [m]
    DC
    CGG
    1750.0
    [m]
    DC
    CGG
    1770.0
    [m]
    DC
    CGG
    1780.0
    [m]
    DC
    CGG
    1790.0
    [m]
    DC
    CGG
    1800.0
    [m]
    DC
    CGG
    1820.0
    [m]
    DC
    CGG
    1840.0
    [m]
    DC
    CGG
    1860.0
    [m]
    DC
    CGG
    1870.0
    [m]
    DC
    CGG
    1910.0
    [m]
    DC
    CGG
    1923.0
    [m]
    DC
    CGG
    1935.0
    [m]
    DC
    CGG
    1947.0
    [m]
    DC
    CGG
    1959.0
    [m]
    DC
    CGG
    1971.0
    [m]
    DC
    CGG
    1977.0
    [m]
    DC
    CGG
    1980.0
    [m]
    DC
    CGG
    1986.0
    [m]
    DC
    CGG
    1988.0
    [m]
    SWC
    CGG
    1989.0
    [m]
    DC
    CGG
    1992.0
    [m]
    C
    CGG
    1995.0
    [m]
    C
    CGG
    1999.0
    [m]
    C
    CGG
    2000.8
    [m]
    C
    CGG
    2002.0
    [m]
    C
    CGG
    2004.6
    [m]
    C
    CGG
    2005.0
    [m]
    C
    CGG
    2006.0
    [m]
    C
    CGG
    2009.2
    [m]
    C
    CGG
    2011.0
    [m]
    C
    CGG
    2013.6
    [m]
    C
    CGG
    2018.0
    [m]
    C
    CGG
    2021.0
    [m]
    C
    CGG
    2024.1
    [m]
    C
    CGG
    2027.0
    [m]
    C
    CGG
    2030.7
    [m]
    C
    CGG
    2035.0
    [m]
    C
    CGG
    2036.9
    [m]
    C
    CGG
    2041.0
    [m]
    C
    CGG
    2045.0
    [m]
    C
    CGG
    2045.7
    [m]
    C
    CGG
    2052.0
    [m]
    DC
    CGG
    2062.0
    [m]
    SWC
    CGG
    2067.0
    [m]
    SWC
    CGG
    2082.0
    [m]
    DC
    CGG
    2109.0
    [m]
    DC
    CGG
    2115.0
    [m]
    SWC
    CGG
    2119.0
    [m]
    SWC
    CGG
    2124.0
    [m]
    DC
    CGG
    2130.4
    [m]
    SWC
    CGG
    2136.0
    [m]
    DC
    CGG
    2160.0
    [m]
    DC
    CGG
    2166.0
    [m]
    DC
    CGG
    2184.0
    [m]
    DC
    CGG
    2196.0
    [m]
    DC
    CGG
    2202.0
    [m]
    DC
    CGG
    2208.0
    [m]
    DC
    CGG

  • Lithostratigraphy

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    GR VSI4
    161
    2588
    GR XLROCK
    1687
    2588
    MWD - ARC9 TELE
    565
    1687
    MWD - ARCRES6 TELE
    1687
    2590
    MWD - ARCVRES9 TELE
    193
    565
    PEX AIT XPT MSIP
    1690
    2588

  • 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
    193.0
    36
    193.0
    0.00
    INTERM.
    13 3/8
    560.2
    17 1/2
    565.0
    0.00
    LINER
    9 5/8
    1685.5
    12 1/4
    1687.0
    1.51
    FIT
    OPEN HOLE
    2590.0
    8 1/2
    2590.0
    0.00

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    193
    1.35
    15.0
    Glydril
    193
    1.05
    16.0
    Spud Mud
    193
    1.60
    18.0
    Kill fluid
    291
    1.05
    16.0
    Spud Mud
    565
    1.30
    12.0
    Glydril
    565
    1.35
    15.0
    Glydril
    568
    1.30
    13.0
    Glydril
    1179
    1.30
    15.0
    Glydril
    1678
    1.28
    18.0
    EMS 4400
    1686
    1.32
    17.0
    Glydril
    1686
    1.30
    15.0
    Glydril
    1818
    1.28
    16.0
    EMS 4400
    2047
    1.28
    19.0
    EMS 4400
    2295
    1.28
    23.0
    EMS 4400
    2590
    1.28
    23.0
    EMS 4400