Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
24.11.2024 - 01:27
Time of last synchronization with Norwegian Offshore Directorate's internal systems

25/1-8 S

Export: PDF icon PDF

  • General information
    General information
    Attribute Value
    Wellbore name
    Official name of wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    25/1-8 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).
    APPRAISAL
    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.
    SUSPENDED
    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.
    25/1-8
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    L 73 - 59 - 54 SP. 1105
    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.
    Elf Petroleum 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.
    466-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.
    59
    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,
    28.05.1985
    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.
    25.07.1985
    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.
    25.07.1987
    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.
    APPRAISAL
    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/GAS
    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
    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.
    FRIGG FM
    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.
    102.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2650.0
    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).
    2572.0
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    65
    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° 54' 3.28'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 6' 9.79'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6640871.09
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    449800.69
    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.
    472

  • Wellbore history
    General
    The Frigg Field was discovered by well 25/1-1 in 1971 and set in production in May 1977. Well 25/1-8 S was drilled to monitor changes in gas/fluid contact, uncover permeability barriers and pressure gradients in the Frigg Formation, refine the geological model, and provide ties for seismic interpretations. Before production started the Frigg Field fluid contacts were: OWC = 1955.9 m TVD MSL and GOC = 1948.2 m TVD MSL. Due to the close proximity to the Odin pipeline, the well had to be drilled with a slight deviation. The well was to be entered several times to monitor further changes in the gas/water contact as a response to field production.
    Operations and results
    Appraisal well 25/1-8 S was spudded with the semi-submersible installation Byford Dolphin on28 May 1985 and drilled to TD at 2650 m (2572 m TVD / 2547 m TVD MSL) in the Paleocene Lista Formation.
    Top Frigg Formation came in at 1930.2 m (1853 m TVD MSL). The formation was gas-bearing with a water saturation of only 6.1% in the gas zone down to the gas/water contact (GWC) at 1901.5 m TVD MSL. A residual gas zone with 74.9% water saturation was found from 1901.5 m TVD MSL down to 1909.3 m TVD MSL. Within this zone, at 1903.5 m TVD MSL was a thin oil layer, which indicated a fingering effect caused by edge water drive. Otherwise the original oil-leg in Frigg had been all swept by water since production start. A three phase zone (oil+gas+water) with 51.5% water saturation was seen below the gas zone from 1909.3 m TVD MSL down to the original GOC at 1948.2 m TVD MSL, and from 1948.2 TVD MSL down to 1981.1 m TVD MSL there was a zone of residual oil and water with 88.2% water saturation. Below 1981.1 m TVD MSL there was only water in the porosity.
    A total of 9 cores were cut in the interval between 1939 and 2112 m, covering the whole Frigg gas sand including the fluid contacts. Fifty-six RFT pressure measurements were recorded on three different runs. They proved no pressure barriers throughout the hydrocarbon bearing sands of the Frigg Formation and 10 m into the water zone at 1990 m TVD MSL. The Frigg Formation below this level had 6 pressure barriers based on the RFT data. No wire line fluid samples were taken.
    The well was suspended on 25 July 1985 for later re-entry and monitoring of the reservoir parameters. It is classified as a gas appraisal 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]
    200.00
    2650.00

  • 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
    1939.0
    1948.9
    [m ]
    2
    1950.0
    1953.2
    [m ]
    3
    1953.2
    1968.3
    [m ]
    4
    1971.0
    1996.5
    [m ]
    5
    1997.8
    1999.0
    [m ]
    6
    2025.0
    2055.0
    [m ]
    7
    2055.0
    2082.5
    [m ]
    8
    2082.5
    2094.4
    [m ]
    9
    2094.4
    2110.5
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    140.4
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 1939-1942m
    Core photo at depth: 1942-1946m
    Core photo at depth: 1946-1950m
    Core photo at depth: 1950-1952m
    Core photo at depth: 1952-1956m
    1939-1942m
    1942-1946m
    1946-1950m
    1950-1952m
    1952-1956m
    Core photo at depth: 1956-1960m
    Core photo at depth: 1960-1964m
    Core photo at depth: 1964-1968m
    Core photo at depth: 1970-1974m
    Core photo at depth: 1974-1977m
    1956-1960m
    1960-1964m
    1964-1968m
    1970-1974m
    1974-1977m
    Core photo at depth: 1978-1982m
    Core photo at depth: 1982-1986m
    Core photo at depth: 1986-1990m
    Core photo at depth: 1990-1994m
    Core photo at depth: 1994-1996m
    1978-1982m
    1982-1986m
    1986-1990m
    1990-1994m
    1994-1996m
    Core photo at depth: 1997-1999m
    Core photo at depth: 2025-2029m
    Core photo at depth: 2029-2033m
    Core photo at depth: 2033-2037m
    Core photo at depth: 2037-2041m
    1997-1999m
    2025-2029m
    2029-2033m
    2033-2037m
    2037-2041m
    Core photo at depth: 2041-2045m
    Core photo at depth: 2045-2049m
    Core photo at depth: 2049-2050m
    Core photo at depth: 2053-2057m
    Core photo at depth: 2057-2061m
    2041-2045m
    2045-2049m
    2049-2050m
    2053-2057m
    2057-2061m
    Core photo at depth: 2061-2064m
    Core photo at depth: 2065-2069m
    Core photo at depth: 2069-2070m
    Core photo at depth: 2080-2084m
    Core photo at depth: 2084-2087m
    2061-2064m
    2065-2069m
    2069-2070m
    2080-2084m
    2084-2087m
    Core photo at depth: 2098-2102m
    Core photo at depth: 2102-2106m
    Core photo at depth: 2106-2110m
    Core photo at depth:  
    Core photo at depth:  
    2098-2102m
    2102-2106m
    2106-2110m

  • Lithostratigraphy
    Lithostratigraphy
    Top depth [mMD RKB]
    Lithostrat. unit
    127
    731
    1930
    2232
    2232
    2237
    2250
    2329
    2532

  • 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
    1.57
    pdf
    0.83

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    BGT
    187
    1896
    CBL VDL
    120
    1015
    CBL VDL
    748
    1868
    CBL VDL
    1741
    2117
    CET
    1740
    2120
    CST
    0
    0
    DISFL LSS GR
    1812
    2644
    DLL MSFL GR
    1912
    2150
    ISF LSS GR
    187
    2108
    LDT CNL
    1912
    2644
    LDT GR
    187
    1897
    RFT
    1930
    2103
    RFT
    1930
    2240
    RFT
    1941
    2508
    SHDT
    1912
    2645
    TDT
    1910
    2128
    VSP WA
    300
    2460

  • 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
    187.5
    36
    190.0
    0.00
    LOT
    INTERM.
    13 3/8
    1015.0
    17 1/2
    1030.0
    1.44
    LOT
    INTERM.
    9 5/8
    1910.0
    12 1/4
    1921.0
    1.69
    LOT
    LINER
    7
    2201.0
    8 1/2
    2650.0
    1.40
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    165
    1.07
    120.0
    WATER BASED
    29.05.1985
    190
    1.07
    150.0
    WATER BASED
    31.05.1985
    209
    1.04
    WATER BASED
    03.06.1985
    527
    1.08
    18.0
    19.0
    WATER BASED
    03.06.1985
    594
    1.07
    19.0
    15.5
    WATER BASED
    03.06.1985
    897
    1.09
    21.0
    15.5
    WATER BASED
    04.06.1985
    1030
    1.10
    24.0
    17.0
    WATER BASED
    04.06.1985
    1030
    1.15
    26.0
    14.0
    WATER BASED
    05.06.1985
    1030
    1.15
    26.0
    14.0
    WATER BASED
    10.06.1985
    1030
    1.15
    26.0
    14.0
    WATER BASED
    05.06.1985
    1030
    1.15
    26.0
    14.0
    WATER BASED
    10.06.1985
    1072
    1.11
    30.0
    10.5
    WATER BASED
    10.06.1985
    1279
    1.12
    33.0
    12.5
    WATER BASED
    13.06.1985
    1451
    1.14
    12.0
    25.0
    WATER BASED
    13.06.1985
    1587
    1.16
    32.0
    12.0
    WATER BASED
    13.06.1985
    1739
    1.16
    26.0
    10.0
    WATER BASED
    13.06.1985
    1908
    1.20
    23.0
    11.0
    WATER BASED
    17.06.1985
    1921
    1.23
    26.0
    8.0
    WATER BASED
    19.06.1985
    1921
    1.23
    26.0
    8.0
    WATER BASED
    28.06.1985
    1921
    1.06
    15.0
    5.0
    WATER BASED
    28.06.1985
    1921
    1.23
    26.0
    8.0
    WATER BASED
    18.06.1985
    1921
    1.05
    19.0
    5.0
    WATER BASED
    02.07.1985
    1921
    1.23
    26.0
    8.0
    WATER BASED
    17.06.1985
    1921
    1.23
    26.0
    8.0
    WATER BASED
    18.06.1985
    1921
    1.23
    26.0
    8.0
    WATER BASED
    19.06.1985
    1921
    1.23
    26.0
    8.0
    WATER BASED
    28.06.1985
    1921
    1.06
    15.0
    5.0
    WATER BASED
    28.06.1985
    1921
    1.05
    19.0
    5.0
    WATER BASED
    02.07.1985
    1925
    1.04
    17.0
    5.0
    WATER BASED
    02.07.1985
    1927
    1.05
    18.0
    5.0
    WATER BASED
    03.07.1985
    1929
    1.06
    27.0
    9.5
    WATER BASED
    04.07.1985
    1950
    1.07
    24.0
    8.5
    WATER BASED
    04.07.1985
    1970
    1.08
    24.0
    8.0
    WATER BASED
    08.07.1985
    2053
    1.08
    27.0
    7.5
    WATER BASED
    08.07.1985
    2099
    1.10
    28.0
    8.0
    WATER BASED
    08.07.1985
    2112
    1.10
    23.0
    6.5
    WATER BASED
    08.07.1985
    2192
    1.10
    24.0
    8.5
    WATER BASED
    09.07.1985
    2419
    1.10
    22.0
    8.0
    WATER BASED
    11.07.1985
    2591
    1.10
    28.0
    7.0
    WATER BASED
    11.07.1985
    2650
    1.13
    30.0
    9.0
    WATER BASED
    14.07.1985
    2650
    1.13
    52.0
    10.0
    WATER BASED
    16.07.1985
    2650
    1.13
    52.0
    10.0
    WATER BASED
    16.07.1985

  • Thin sections at the Norwegian Offshore Directorate
    Thin sections at the Norwegian Offshore Directorate
    Depth
    Unit
    1948.00
    [m ]

  • 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
    0.22