Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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22.12.2024 - 01:25
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25/9-1

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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.
    25/9-1
    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
    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
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    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.
    25/9-1
    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.
    Amerada Hess Norge 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.
    810-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,
    28.03.1995
    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.
    22.04.1995
    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.
    22.04.1997
    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.
    29.08.2003
    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
    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.
    111.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2525.0
    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).
    2525.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    1.5
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    91
    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 TRIASSIC
    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.
    SMITH BANK FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    59° 26' 58.72'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 42' 35.67'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6590310.69
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    483550.58
    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.
    2476

  • Wellbore history
    General
    Well 25/9-1 is located East of the Jotun area and Southwest of the small 25/6-1 Discovery. Well 25/9-1 was drilled to test the hydrocarbon potential of Middle Jurassic Hugin Formation sandstones (Rummel prospect) with sandstones of the Lower Palaeocene Ty Formation as a secondary target.
    Operations and results
    Wildcat well 25/9-1 was spudded with the semi-submersible "Vildkat Explorer" 28 March 1995 and drilled to a total depth of 2525 m as prognosed, 110.5 m into sediments of the Late Triassic Smith Bank Formation. The well was drilled with bentonite / sea water down to 1056 m and with "Anco 2000" mud with ca 3% "Anco 208" glycols from 1056 m to TD.
    No shallow gas or boulder beds were encountered in the uppermost well section. The well penetrated mainly clays and claystones in the Nordland, Hordaland and Rogaland groups. A clean Quaternary sandstone was seen between 275 and 319 m. The Utsira (754.5 m - 1000 m) and Skade (1284.5 m -1344.5 m) Formation sandstones were also present. Top Våle Formation was reached at 2030.5 m but no Ty Formation sands were present and the lithology consisted mainly of limestones and chalk, which continued down to top Shetland Group at 2043.5 m. The Shetland Group consisted mainly of chalk with the Cromer Knoll Group consisting of limestones interbedded with clay stones and marls. The Hugin Formation sandstones came in as prognosed at 2184.5 m and were found to be water bearing. One 11.5 metre core was cut. The core showed excellent reservoir parameters.
    No hydrocarbons were found in the Våle Formation. Weak shows were seen in drilled cuttings from two intervals; the Lista Formation from 1951 m to 2017 m and in the Draupne and Heather formations from 2167 to 2184.5 m and in a number of sidewall cores recovered from wire line log run 2F, interval 1988 m to 2413 m. Post well organic geochemical analysis confirmed traces of migrated hydrocarbons present in the interval 2180 m - 2183 m (Heather Formation). Except from the above mentioned shows, MWD and wire line log responses did not indicate any presence of hydrocarbons throughout the well. No fluid samples were taken in the well. The well was permanently abandoned as dry well 22 April 1995.
    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]
    1060.00
    2525.00

  • 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
    2183.0
    2194.5
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    11.5
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 2183-2188m
    Core photo at depth: 2188-2193m
    Core photo at depth: 2193-2195m
    Core photo at depth:  
    Core photo at depth:  
    2183-2188m
    2188-2193m
    2193-2195m

  • 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
    208.0
    36
    208.0
    0.00
    LOT
    SURF.COND.
    13 3/8
    1043.0
    17 1/2
    1044.0
    0.00
    LOT
    INTERM.
    9 5/8
    1960.0
    12 1/4
    1960.0
    0.00
    LOT
    OPEN HOLE
    2525.0
    8 1/2
    2525.0
    0.00
    LOT

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CAL CN GR
    2300
    2523
    FMT GR QUARTZDYNE
    2188
    2474
    HEXDIP GR
    1966
    2517
    MLL DLL AC GR SP CAL
    1966
    2523
    MLL DLL AC SL SP CAL
    1044
    1952
    MLL DLL SL SP CAL
    1044
    1946
    MWD - DIR FE
    136
    400
    MWD - DIR FE
    1015
    1970
    MWD - DIR FE
    1972
    2184
    MWD - DIR FE
    2194
    2525
    SWC GR
    1272
    1945
    SWC GR
    1981
    2521
    VSP
    1160
    2470
    ZDL CN SL
    1966
    2523

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.29

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    1.63
    pdf
    1.19

  • 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
    38.46

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    208
    1.08
    100.0
    WATER BASED
    323
    1.05
    100.0
    WATER BASED
    434
    1.08
    100.0
    WATER BASED
    1004
    1.08
    100.0
    WATER BASED
    1056
    1.27
    22.0
    WATER BASED
    1705
    1.27
    21.0
    WATER BASED
    1850
    1.28
    16.0
    WATER BASED
    1970
    1.27
    29.0
    WATER BASED
    2082
    1.27
    19.0
    WATER BASED
    2183
    1.27
    27.0
    WATER BASED
    2304
    1.27
    20.0
    WATER BASED
    2525
    1.27
    20.0
    WATER BASED

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1272.0
    [m]
    SWC
    RRI
    1366.5
    [m]
    SWC
    RRI
    1435.0
    [m]
    SWC
    RRI
    1665.0
    [m]
    SWC
    RRI
    1743.1
    [m]
    SWC
    RRI
    1760.0
    [m]
    DC
    RRI
    1770.0
    [m]
    DC
    RRI
    1785.5
    [m]
    SWC
    RRI
    1799.0
    [m]
    SWC
    RRI
    1810.0
    [m]
    DC
    RRI
    1818.5
    [m]
    SWC
    RRI
    1824.5
    [m]
    SWC
    RRI
    1829.8
    [m]
    SWC
    RRI
    1835.0
    [m]
    SWC
    RRI
    1840.0
    [m]
    DC
    RRI
    1850.5
    [m]
    SWC
    RRI
    1860.0
    [m]
    DC
    RRI
    1870.0
    [m]
    DC
    RRI
    1880.0
    [m]
    DC
    RRI
    1882.0
    [m]
    SWC
    RRI
    1892.5
    [m]
    SWC
    RRI
    1899.8
    [m]
    SWC
    RRI
    1900.0
    [m]
    DC
    RRI
    1910.0
    [m]
    SWC
    RRI
    1915.5
    [m]
    SWC
    RRI
    1923.2
    [m]
    SWC
    RRI
    1939.0
    [m]
    SWC
    RRI
    1942.9
    [m]
    SWC
    RRI
    1950.0
    [m]
    DC
    RRI
    1960.0
    [m]
    DC
    RRI
    1970.0
    [m]
    DC
    RRI
    1988.0
    [m]
    SWC
    RRI
    2001.0
    [m]
    DC
    RRI
    2013.5
    [m]
    SWC
    RRI
    2015.5
    [m]
    SWC
    RRI
    2019.0
    [m]
    DC
    RRI
    2030.0
    [m]
    SWC
    RRI
    2039.0
    [m]
    SWC
    RRI
    2041.0
    [m]
    SWC
    RRI
    2043.0
    [m]
    DC
    RRI
    2044.0
    [m]
    SWC
    RRI
    2055.0
    [m]
    DC
    RRI
    2070.0
    [m]
    DC
    RRI
    2074.5
    [m]
    SWC
    RRI
    2079.5
    [m]
    SWC
    RRI
    2100.0
    [m]
    DC
    RRI
    2109.0
    [m]
    DC
    RRI
    2114.0
    [m]
    SWC
    RRI
    2118.0
    [m]
    DC
    RRI
    2130.0
    [m]
    DC
    RRI
    2145.0
    [m]
    DC
    RRI
    2154.0
    [m]
    DC
    RRI
    2157.0
    [m]
    DC
    RRI
    2160.0
    [m]
    DC
    RRI
    2163.0
    [m]
    DC
    RRI
    2165.5
    [m]
    SWC
    RRI
    2168.0
    [m]
    SWC
    RRI
    2174.5
    [m]
    SWC
    RRI
    2177.0
    [m]
    SWC
    RRI
    2181.0
    [m]
    SWC
    RRI
    2183.0
    [m]
    C
    RRI
    2185.5
    [m]
    SWC
    RRI
    2187.2
    [m]
    C
    RRI
    2189.3
    [m]
    C
    RRI
    2190.0
    [m]
    SWC
    RRI
    2192.8
    [m]
    C
    RRI
    2193.5
    [m]
    C
    RRI
    2194.5
    [m]
    C
    RRI
    2212.5
    [m]
    SWC
    RRI
    2226.0
    [m]
    DC
    RRI
    2241.0
    [m]
    DC
    RRI
    2268.0
    [m]
    DC
    RRI
    2283.0
    [m]
    DC
    RRI
    2286.8
    [m]
    SWC
    RRI
    2299.5
    [m]
    SWC
    RRI
    2302.0
    [m]
    SWC
    RRI
    2322.0
    [m]
    DC
    RRI
    2332.0
    [m]
    SWC
    RRI
    2343.0
    [m]
    SWC
    RRI
    2355.0
    [m]
    DC
    RRI
    2361.5
    [m]
    SWC
    RRI
    2367.0
    [m]
    DC
    RRI
    2389.5
    [m]
    SWC
    RRI
    2400.0
    [m]
    DC
    RRI
    2413.0
    [m]
    SWC
    RRI
    2433.5
    [m]
    SWC
    RRI
    2445.0
    [m]
    DC
    RRI
    2460.0
    [m]
    DC
    RRI
    2478.5
    [m]
    SWC
    RRI
    2494.0
    [m]
    SWC
    RRI
    2505.0
    [m]
    DC
    RRI
    2522.0
    [m]
    DC
    RRI

  • Thin sections at the Norwegian Offshore Directorate
    Thin sections at the Norwegian Offshore Directorate
    Depth
    Unit
    2193.50
    [m ]
    2194.20
    [m ]
    2183.50
    [m ]
    2193.00
    [m ]
    2183.25
    [m ]