Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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22.11.2024 - 09:09
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25/9-3

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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.
    25/9-3
    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.
    25/9-3
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    NO 07M01-inline 2909 & crossline 4190
    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.
    Norwegian Energy Company ASA
    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.
    1269-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.
    24
    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,
    28.08.2009
    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.
    20.09.2009
    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.
    20.09.2011
    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.
    30.09.2011
    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.
    18.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    121.5
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2267.0
    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).
    2267.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    1.4
    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.
    EARLY 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.
    STATFJORD GP
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    59° 26' 5.03'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 40' 42.88'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6588658.01
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    481766.00
    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.
    6189

  • Wellbore history
    General
    Well 25/9-3 was drilled on the Tasta prospect in the Northern part of the Utsira High in the North Sea. The primary objective of the well was to test the hydrocarbon potential of the Middle Jurassic Hugin Formation.TD was to be set 50 m into the Statfjord Formation.
    Operations and results
    Wildcat well 25/9-3 was spudded with the semi-submersible installation West Alpha on 28 August 2009 and drilled to TD at 2267 m in the Early Jurassic Statfjord Formation. A 9 7/8" pilot hole was drilled from below the 30" shoe to the setting depth for the 13 3/8" casing at 1180 meters. No shallow gas was encountered at the well location. No significant problems were encountered in the operations. The well was drilled with hi-vis sweeps/seawater/bentonite mud down to 1180 m and with Glydril mud (2.5 - 3.5 % glycol) from 1180 m to TD.
    The 8 1/2" section was drilled through a condensed sequence of Cretaceous sediments down to the Jurassic target, Hugin Formation. Top reservoir was encountered at 2103.4 m, 4 m shallower relative to prognosis. It had a gross thickness of approximately 10 m containing two sandstone units separated by a 1.8 m thick claystone/coal layer in the middle. Both sandstone sequences had good reservoir properties, but contained no hydrocarbons. The Statfjord Fm encountered at approximately 2218 m was found, as expected, water bearing. No shows of any sort were recorded in the well. Post-well geochemical analyses proved rich, but immature source rocks in the Draupne, Heather, Hugin and Statfjord formations.
    No cores were cut and no wire line fluid samples were taken. At TD, a reduced dry hole case scenario logging program was performed.
    The well was permanently abandoned on 20 September 2009 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]
    1190.00
    2267.00

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1790.0
    [m]
    DC
    APT
    1810.0
    [m]
    DC
    APT
    1830.0
    [m]
    DC
    APT
    1850.0
    [m]
    DC
    APT
    1870.0
    [m]
    DC
    APT
    1890.0
    [m]
    DC
    APT
    1900.0
    [m]
    DC
    APT
    1910.0
    [m]
    DC
    APT
    1920.0
    [m]
    DC
    APT
    1930.0
    [m]
    DC
    APT
    1940.0
    [m]
    DC
    APT
    1950.0
    [m]
    DC
    APT
    1960.0
    [m]
    DC
    APT
    1970.0
    [m]
    DC
    APT
    1980.0
    [m]
    DC
    APT
    1990.0
    [m]
    DC
    APT
    2000.0
    [m]
    DC
    APT
    2010.0
    [m]
    DC
    APT
    2020.0
    [m]
    DC
    APT
    2030.0
    [m]
    DC
    APT
    2040.0
    [m]
    DC
    APT
    2050.0
    [m]
    DC
    APT
    2058.0
    [m]
    DC
    APT
    2067.0
    [m]
    DC
    APT
    2076.0
    [m]
    DC
    APT
    2085.0
    [m]
    DC
    APT
    2091.0
    [m]
    DC
    APT
    2094.0
    [m]
    DC
    APT
    2097.0
    [m]
    DC
    APT
    2100.0
    [m]
    DC
    APT
    2103.0
    [m]
    DC
    APT
    2106.0
    [m]
    DC
    APT
    2109.0
    [m]
    DC
    APT
    2112.0
    [m]
    DC
    APT
    2115.0
    [m]
    DC
    APT
    2124.0
    [m]
    DC
    APT
    2133.0
    [m]
    DC
    APT
    2142.0
    [m]
    DC
    APT
    2169.0
    [m]
    DC
    APT
    2175.0
    [m]
    DC
    APT
    2184.0
    [m]
    DC
    APT
    2193.0
    [m]
    DC
    APT
    2202.0
    [m]
    DC
    APT
    2211.0
    [m]
    DC
    APT
    2220.0
    [m]
    DC
    APT
    2229.0
    [m]
    DC
    APT
    2241.0
    [m]
    DC
    APT
    2250.0
    [m]
    DC
    APT
    2259.0
    [m]
    DC
    APT
    2267.0
    [m]
    DC
    APT

  • Lithostratigraphy

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    txt
    0.00
    txt
    0.09

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    LWD - DIR
    223
    1179
    LWD - GR RES APWD DIR
    223
    1180
    LWD - GR RES APWD DIR
    1180
    1951
    LWD - GR RES APWD DIR
    1951
    2267
    PEX HRLA DSI APT
    1946
    2247

  • 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
    217.0
    36
    223.0
    0.00
    LOT
    SURF.COND.
    13 3/8
    1173.0
    17 1/2
    1180.0
    1.70
    LOT
    PILOT HOLE
    1180.0
    9 7/8
    1180.0
    0.00
    LOT
    INTERM.
    9 5/8
    1946.0
    12 1/4
    1951.0
    1.83
    LOT
    OPEN HOLE
    2267.0
    8 1/2
    2267.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    223
    1.03
    SW/Hi-VIS
    1180
    1.03
    SW/Hi-VIS
    1951
    1.30
    Glydril WBM
    2267
    1.33
    Glydril WBM