Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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sodir.no          Norsk
31.10.2024 - 01:27
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25/8-7

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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.
    25/8-7
    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
    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.
    25/8-7
    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.
    818-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.
    23
    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,
    21.07.1995
    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.
    12.08.1995
    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.
    12.08.1997
    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.
    OIL SHOWS
    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.
    123.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2380.0
    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).
    2379.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    3.7
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    81
    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.
    AMUNDSEN FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    59° 28' 28.43'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 34' 28.57'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6593127.02
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    475896.00
    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.
    2612

  • Wellbore history
    General
    Exploration Well 25/8-7 is located East North-East of the Jotun Field. The two main objectives for drilling well 25/8-7 were to test the hydrocarbon potentials of the sandstones in the Lower Palaeocene Heimdal Formation (Krap prospect) and in the Middle Jurassic Hugin Formation.
    Operations and results
    Well 25/8-7 was spudded with the semi-submersible installation "Dyvi Stena" on 21 July 1995 and drilled to a total depth of 2380 m, 40 metres into the Early Jurassic Amundsen Formation. The well was drilled with seawater and high viscous pills through the 36" and 17 1/2" hole sections down to 1070 m. After setting the 13 3/8" casing the mud system was changed to a 1.27 SG KCL/ polymer system with 3 - 4 % glycol added for drilling the 12 1/4" and 8 1/2" sections to final 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. Grid Formation sands were encountered from 1293 m to 1348 m and 1484 m to 1504 m. Minor thin distal remnants of the Heimdal Formation sands were encountered between 2050 and 2061.5 metres, however these proved water wet. Top Ty Formation was reached at 2157 m, consisting of clean sandstone divided by a thin shale bed. It continued down to top Shetland Group at 2209 metres. No hydrocarbons were found in the Ty Formation. The Shetland Group consisted mainly of chalk with the Cromer Knoll Group consisting of limestones interbedded with claystones and marls. The Hugin Formation sandstones came in at 2318 m and were found to be water bearing. Traces of dark brown tarry dead oil staining together with weak, dull yellow fluorescence and slight petroliferous odour was seen in the Heimdal Formation sands and claystones from 2050 m to 2061.5 m. Similarly traces of dark brown tarry dead oil stained grains were described at the top of the Hugin Formation at 2318 m and in a sidewall core recovered from 2315 m. Post well organic geochemical analysis performed by Geolab Nor indicates hydrocarbons, possibly locally migrated, occur throughout the Heimdal Formation interbedded sand and claystones section. Traces of migrated liquid hydrocarbons are present in the Ty Formation interval 2187 m - 2199 m with larger amounts detected in the Hugin Formation at around 2319 m and in the underlying Sleipner Formation sands, e.g. at 2333 m. Three cores were cut in the 8 1/2" hole section. Two cores, totalling 8.9 metres of sand and clay were cut in the Heimdal Formation and one 19.68 metre core was cut in excellent reservoir sands of the Hugin Formation.
    One FMT fluid sample was taken at 2105.5 m in the Våle Formation. The 10 l clean-up chamber was drained at well-site and contained only mud filtrate and formation water, the 4 l PVT chamber was sent onshore and flash to stock-tank conditions in laboratory gave gas and water with a gas/water ratio of 2.2 Sm3/Sm3. The gas gravity (air = 1) was 0.5956. The well was permanently abandoned as a well with shows on 12 August 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]
    1080.00
    2378.00

  • 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
    2053.0
    2053.7
    [m ]
    2
    2053.0
    2061.9
    [m ]
    3
    2319.0
    2338.7
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    29.3
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 2053-2054m
    Core photo at depth: 2054-2058m
    Core photo at depth: 2058-2062m
    Core photo at depth: 2319-2324m
    Core photo at depth: 2324-2329m
    2053-2054m
    2054-2058m
    2058-2062m
    2319-2324m
    2324-2329m
    Core photo at depth: 2329-2334m
    Core photo at depth: 2334-2339m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    2329-2334m
    2334-2339m

  • 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
    219.0
    36
    220.0
    0.00
    LOT
    SURF.COND.
    13 3/8
    1057.0
    17 1/2
    1060.0
    0.00
    LOT
    INTERM.
    9 5/8
    1995.0
    12 1/4
    2000.0
    0.00
    LOT
    OPEN HOLE
    2380.0
    8 1/2
    2380.0
    0.00
    LOT

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    FMT HP GR
    0
    0
    FMT HP GR
    2027
    2160
    FMT HP GR
    2037
    2338
    HEXDIP GR
    1992
    2375
    MLL DLL DAC SL CAL
    1056
    1932
    MLL DLL DAC SL CAL
    1056
    1932
    MLL DLL MAC GR CAL
    1992
    2379
    MWD - D-RAW
    148
    225
    MWD - D-RAW
    225
    1070
    MWD DPR-RAW
    1070
    1411
    MWD DPR-RAW
    1411
    2010
    MWD DPR-RAW
    2010
    2053
    MWD DPR-RAW
    2053
    2319
    MWD DPR-RAW
    2319
    2380
    SWC GR
    1294
    1928
    SWC GR
    2017
    2370
    SWC GR
    2017
    2370
    VSP
    980
    2230
    VSP
    2220
    2360
    ZDL CN SL
    1992
    2376

  • Lithostratigraphy

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    1.78
    pdf
    0.84

  • 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
    84.61

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    1074
    1.27
    72.0
    WATER BASED
    1411
    1.27
    62.0
    WATER BASED
    1855
    1.29
    16.0
    WATER BASED
    2010
    1.29
    52.0
    WATER BASED
    2042
    1.26
    16.0
    WATER BASED
    2059
    1.26
    49.0
    WATER BASED
    2186
    1.26
    13.0
    WATER BASED
    2319
    1.26
    46.0
    WATER BASED
    2341
    1.26
    14.0
    WATER BASED
    2380
    1.26
    14.0
    WATER BASED

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1750.5
    [m]
    SWC
    RRI
    1760.0
    [m]
    DC
    RRI
    1772.5
    [m]
    SWC
    RRI
    1780.0
    [m]
    DC
    RRI
    1794.5
    [m]
    SWC
    RRI
    1805.0
    [m]
    DC
    RRI
    1810.0
    [m]
    DC
    RRI
    1824.5
    [m]
    SWC
    RRI
    1830.5
    [m]
    SWC
    RRI
    1840.0
    [m]
    DC
    RRI
    1852.5
    [m]
    SWC
    RRI
    1860.0
    [m]
    DC
    RRI
    1875.5
    [m]
    SWC
    RRI
    1882.5
    [m]
    SWC
    RRI
    1900.0
    [m]
    DC
    RRI
    1916.5
    [m]
    SWC
    RRI
    1928.7
    [m]
    SWC
    RRI
    1941.0
    [m]
    DC
    RRI
    1950.0
    [m]
    DC
    RRI
    1959.0
    [m]
    DC
    RRI
    1968.0
    [m]
    DC
    RRI
    1980.0
    [m]
    DC
    RRI
    1992.0
    [m]
    DC
    RRI
    2000.0
    [m]
    DC
    RRI
    2010.0
    [m]
    DC
    RRI
    2022.0
    [m]
    SWC
    RRI
    2031.0
    [m]
    SWC
    RRI
    2037.0
    [m]
    DC
    RRI
    2048.5
    [m]
    SWC
    RRI
    2054.0
    [m]
    C
    RRI
    2054.5
    [m]
    SWC
    RRI
    2058.0
    [m]
    C
    RRI
    2061.0
    [m]
    DC
    RRI
    2061.9
    [m]
    C
    RRI
    2067.0
    [m]
    SWC
    RRI
    2082.0
    [m]
    DC
    RRI
    2093.0
    [m]
    SWC
    RRI
    2100.0
    [m]
    DC
    RRI
    2105.5
    [m]
    SWC
    RRI
    2121.0
    [m]
    DC
    RRI
    2130.0
    [m]
    SWC
    RRI
    2139.0
    [m]
    DC
    RRI
    2148.0
    [m]
    SWC
    RRI
    2156.0
    [m]
    SWC
    RRI
    2172.0
    [m]
    DC
    RRI
    2178.0
    [m]
    DC
    RRI
    2187.5
    [m]
    SWC
    RRI
    2199.0
    [m]
    DC
    RRI
    2211.0
    [m]
    SWC
    RRI
    2223.0
    [m]
    SWC
    RRI
    2230.0
    [m]
    DC
    RRI
    2230.0
    [m]
    DC
    RRI
    2240.0
    [m]
    DC
    RRI
    2245.0
    [m]
    DC
    RRI
    2250.0
    [m]
    DC
    RRI
    2260.0
    [m]
    DC
    RRI
    2268.0
    [m]
    SWC
    RRI
    2280.0
    [m]
    SWC
    RRI
    2290.0
    [m]
    DC
    RRI
    2299.0
    [m]
    SWC
    RRI
    2305.5
    [m]
    SWC
    RRI
    2310.0
    [m]
    DC
    RRI
    2318.0
    [m]
    SWC
    RRI
    2322.0
    [m]
    C
    RRI
    2326.0
    [m]
    C
    RRI
    2330.0
    [m]
    C
    RRI
    2330.0
    [m]
    DC
    RRI
    2331.3
    [m]
    C
    RRI
    2336.9
    [m]
    C
    RRI
    2338.7
    [m]
    C
    RRI
    2340.0
    [m]
    SWC
    RRI
    2354.0
    [m]
    SWC
    RRI
    2370.0
    [m]
    SWC
    RRI

  • Thin sections at the Norwegian Offshore Directorate
    Thin sections at the Norwegian Offshore Directorate
    Depth
    Unit
    2319.25
    [m ]
    2061.50
    [m ]
    2055.00
    [m ]
    2333.00
    [m ]
    2054.80
    [m ]
    2335.50
    [m ]
    2054.55
    [m ]
    2320.50
    [m ]
    2322.25
    [m ]
    2325.60
    [m ]
    2053.20
    [m ]
    2053.60
    [m ]
    2053.33
    [m ]
    2053.45
    [m ]