Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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25.11.2024 - 01:30
Time of last synchronization with Norwegian Offshore Directorate's internal systems

25/1-3

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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.
    25/1-3
    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).
    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.
    P&A
    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.
    25/1-3
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    line 65.5954.SP 96
    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.
    65-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.
    75
    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,
    14.11.1971
    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.
    27.01.1972
    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.
    27.01.1974
    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.
    24.09.2015
    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.
    24.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    105.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2872.0
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    67
    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 CRETACEOUS
    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.
    SHETLAND GP
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    59° 54' 5'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 10' 5'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6640876.58
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    453456.52
    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.
    349

  • Wellbore history
    General
    Well 25/1-3 was drilled to appraise the eastward extension of the 25/1-1 Frigg Discovery on the Frigg Ridge in the North Sea. The primary objective was to test the Eocene sandstones that were gas bearing in well 25/1-1.
    Operations and results
    Appraisal well 25/1-3 was spudded with the semi-submersible installation Pentagone 81 on 14 November 1971 and drilled to TD at 2872 m in the Late Cretaceous  Shetland Group. The well was drilled with seawater down to 405 m and with a seawater/LFC mud from 405 m to TD.
    The target Eocene sandstones (Frigg Formation) was penetrated at 1952 m. The gross thickness was 217 m and the N/G was 0.82 with porosities ranging from 28 to 33%. It was gas bearing down to the GOC at 1973 m and oil bearing down to the OWC at 1982.5 m. Good oil shows on cores were recorded throughout the hydrocarbon-bearing reservoir. Weaker oil shows on cores were described ("fluo but salty taste") below the OWC.
    Three cores were cut from 1951 to 2005 m in the Frigg reservoir. Total recovery for these three cores was 42.25 m (78.2% recovery). A fourth core was cut from 2563 to 2568 m with 50% recovery. FIT fluid samples were attempted at 2550.5 m and 2576.3 m but only mud and filtrate was recovered.
    The well was permanently abandoned on 27 January 1972 as an oil and gas appraisal well
    Testing
    Six drill stem tests were conducted.
    DST 1, 2 and 3 tested the interval 1985 to 1987 m. All three tests produced water.
    DST 4 and 5 tested the interval 1978 to 1980 m. DST 4 produced 21.5 Sm3 oil/day and DST 5 produced 70 Sm3 oil/day. The maximum temperature in these tests was reported to be 63 °C.
    DST 6 tested the interval 1976 to 1980 m and produced in the final flow; through a 24/64" choke an average of 14400 Sm3 gas and 136 Sm3 oil /day. The corresponding GOR is 106 Sm3/Sm3.

  • 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]
    420.00
    2870.00

  • 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
    1951.0
    1965.3
    [m ]
    2
    1969.0
    1982.9
    [m ]
    3
    1991.1
    2005.0
    [m ]
    4
    2563.0
    2565.5
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    44.6
    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
    1775.0
    [m]
    DC
    1795.0
    [m]
    DC
    1815.0
    [m]
    DC
    1835.0
    [m]
    DC
    1855.0
    [m]
    DC
    1875.0
    [m]
    DC
    1895.0
    [m]
    DC
    1925.0
    [m]
    DC
    1930.0
    [m]
    DC
    1935.0
    [m]
    DC
    1945.0
    [m]
    DC
    2025.0
    [m]
    DC
    2045.0
    [m]
    DC
    2065.0
    [m]
    DC
    2085.0
    [m]
    DC
    2105.0
    [m]
    DC
    2125.0
    [m]
    DC
    2145.0
    [m]
    DC
    2160.0
    [m]
    DC
    2180.0
    [m]
    DC
    2200.0
    [m]
    DC
    2220.0
    [m]
    DC
    2245.0
    [m]
    DC
    2265.0
    [m]
    DC
    2285.0
    [m]
    DC
    2305.0
    [m]
    DC
    2325.0
    [m]
    DC
    2345.0
    [m]
    DC
    2365.0
    [m]
    DC
    2385.0
    [m]
    DC
    2405.0
    [m]
    DC
    2425.0
    [m]
    DC
    2448.0
    [m]
    DC
    2476.0
    [m]
    DC
    2496.0
    [m]
    DC
    2516.0
    [m]
    DC
    2536.0
    [m]
    DC
    2552.0
    [m]
    DC
    2564.0
    [m]
    C
    IGS

  • Lithostratigraphy
    Lithostratigraphy
    Top depth [mMD RKB]
    Lithostrat. unit
    129
    835
    1952
    2244
    2244
    2272
    2289
    2492
    2711
    2734

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.21
    pdf
    0.23

  • 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
    1.43
    pdf
    0.51

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    1985
    1987
    0.0
    2.0
    1985
    1987
    0.0
    3.0
    1985
    1987
    0.0
    4.0
    1978
    1980
    0.0
    5.0
    1978
    1980
    0.0
    6.0
    1976
    1980
    0.0
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    2.0
    3.0
    4.0
    5.0
    6.0
    Drill stem tests (DST)
    Test number
    Oil
    [Sm3/day]
    Gas
    [Sm3/day]
    Oil density
    [g/cm3]
    Gas grav. rel.air
    GOR
    [m3/m3]
    1.0
    2.0
    3.0
    4.0
    21
    5.0
    70
    6.0
    84
    110

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    BHC
    150
    2869
    CBL
    1500
    2011
    CDM AP
    1883
    2873
    DL
    1882
    2869
    FDC
    1882
    2874
    IES
    407
    2869
    ML MLL
    1883
    2872
    SNP
    1882
    2874
    SRS
    407
    2873

  • 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
    165.0
    36
    165.0
    0.00
    INTERM.
    13 3/8
    405.0
    17 1/2
    415.0
    0.00
    SURF.COND.
    9 5/8
    1880.0
    12 1/4
    1886.0
    0.00
    LINER
    7
    2036.0
    8 1/2
    2872.0
    0.00

  • 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
    0.21