Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
22.12.2024 - 01:25
Time of last synchronization with Norwegian Offshore Directorate's internal systems

25/1-4

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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.
    25/1-4
    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
    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.
    25/1-4
    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.
    108-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.
    60
    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,
    01.04.1974
    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.
    30.05.1974
    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.
    30.05.1976
    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.
    29.06.2004
    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/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.
    YES
    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.
    107.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2795.0
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    76
    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.
    HARDRÅDE FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    59° 59' 52.51'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 15' 54.8'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6651562.60
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    459011.74
    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.
    350

  • Wellbore history
    General
    Exploration well 25/1-4 was located on a lower Eocene structure straddling the 25/1 and 30/10 blocks limit, north-east of the main Frigg Field. It was drilled to explore additional gas reserves in the Frigg area. A "Bright spot" phenomenon interpreted as a gas/oil or water table is clearly visible on all the seismic sections crossing the structure. Possible Danian and Maastrichtian reservoirs were considered secondary objectives.
    Operations and results
    áWell 25/1-4 was spudded with the semi-submersible installation Deepsea Driller on 1 April 1974 and drilled to TD at 2795 m in Maastrichtian marls.
    The top of the Eocene reservoir (Frigg Formation) at 1967.8 was detected by C1 traces (maximum 3%). Based on shows on cores and electrical logs gas/oil and oil/water contacts were found at 2005.6 m and 2009 m, respectively. The contacts were not the same as on the Frigg Field, implying that this discovery was not in communication with the main Frigg Field. Background gas was weak to nil below 2010 and cuttings or sidewall cores below this depth showed no direct fluorescence or cut. Paleocene was penetrated at 2058 m with well-developed sand bodies as is usual in the area. Hence, the Paleocene contained 190 m net sands of which 25 m consisted of calcareous sandstone and 90 m of shaly sands. All Paleocene sands were water wet. In the Maastrichtian chalk some gas shows were recorded on the section 2757 m to 2763 m. Some hydrocarbon saturation was inferred by logs, but an FIT at 2760 m recovered 2.750 l of mud with only oil traces after a 25 minutes flow period.
    Coring started at 1922 m, 45.8 m above the Eocene sands. Eight conventional cores were cut from this point down to 2028 m. Two wire line tests were conducted in the oil-bearing zone at 2006.5 m and 2007.5 m. The latter recovered 5.15 l of oil and 4.75 l of mud filtrate.
    The well was permanently abandoned on 30 May 1974 as an oil and gas discovery.
    Testing
    One drill stem test was carried out through the 7" liner in the Eocene gas zone (perforations at 1991.20 m to 1995.8 m, 1983.20 m to 1987.2, and 1969.7 m to 1974.3 m). Gas flow was stabilized around 610000 m3/day on 3/4" choke (with 5.04 Sm3 associated condensate/day) and 831400 m3/day on a 1" choke (5.04 Sm3 associated condensate/day).

  • 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]
    450.00
    2795.00

  • 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
    1922.0
    1933.0
    [m ]
    2
    1935.5
    1949.5
    [m ]
    3
    1953.5
    1970.5
    [m ]
    4
    1970.5
    1976.5
    [m ]
    5
    1984.0
    1990.0
    [m ]
    6
    1993.0
    1999.0
    [m ]
    7
    2001.0
    2010.0
    [m ]
    8
    2010.0
    2023.5
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    82.5
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • 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
    164.0
    36
    166.0
    0.00
    LOT
    INTERM.
    13 3/8
    424.0
    17 1/2
    425.0
    0.00
    LOT
    INTERM.
    9 5/8
    1907.0
    12 1/4
    1910.0
    0.00
    LOT
    LINER
    7
    2795.0
    8 1/2
    2795.0
    0.00
    LOT

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    1969
    1995
    19.0
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    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
    5
    610000

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL
    1250
    1907
    CBL
    1758
    2051
    CCL PERF
    1969
    1974
    CCL PERF
    1983
    1987
    CCL PERF
    1991
    1995
    DLL
    1907
    2786
    FDC CNL
    1907
    2078
    FDC CNT
    1907
    2770
    GR
    132
    420
    GR SL
    420
    1919
    GR SL
    1907
    2077
    GR SL
    1907
    2792
    HDT
    1907
    2791
    IES
    425
    1920
    IES
    1907
    2078
    IES
    1907
    2770
    MLL ML
    1907
    2770
    SWC
    2067
    2793
    SWC
    2067
    2793

  • Lithostratigraphy
    Lithostratigraphy
    Top depth [mMD RKB]
    Lithostrat. unit
    133
    952
    1968
    2058
    2058
    2316
    2561
    2643
    2687
    2687

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.32

  • 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
    0.76
    PDF
    8.36
    PDF
    0.35
    PDF
    5.39
    pdf
    3.22
    PDF
    11.32
    PDF
    5.75
    PDF
    0.96
    PDF
    0.62
    PDF
    1.87
    PDF
    0.42
    PDF
    11.21
    PDF
    3.56

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    920
    1.30
    60.0
    12.0
    water based
    1840
    1.38
    75.0
    12.0
    water based
    1930
    1.25
    47.0
    12.0
    water based
    2028
    1.25
    48.0
    14.0
    water based
    2563
    1.25
    46.0
    10.0
    water based

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1780.0
    [m]
    DC
    1800.0
    [m]
    DC
    1820.0
    [m]
    DC
    1840.0
    [m]
    DC
    1860.0
    [m]
    DC
    1880.0
    [m]
    DC
    1900.0
    [m]
    DC
    1921.0
    [m]
    DC
    1925.0
    [m]
    C
    IGS
    1941.0
    [m]
    C
    IGS
    1954.0
    [m]
    C
    IGS
    1970.0
    [m]
    C
    IGS
    1976.0
    [m]
    C
    IGS
    2035.0
    [m]
    DC
    2055.0
    [m]
    DC
    2067.0
    [m]
    SWC
    2075.0
    [m]
    DC
    2095.0
    [m]
    DC
    2115.0
    [m]
    DC
    2119.0
    [m]
    SWC
    2135.0
    [m]
    DC
    2155.0
    [m]
    DC
    2175.0
    [m]
    DC
    2176.0
    [m]
    SWC
    2195.0
    [m]
    DC
    2215.0
    [m]
    DC
    2235.0
    [m]
    DC
    2247.0
    [m]
    SWC
    2255.0
    [m]
    DC
    2275.0
    [m]
    DC
    2300.0
    [m]
    DC
    2320.0
    [m]
    DC
    2340.0
    [m]
    DC
    2360.0
    [m]
    DC
    2371.0
    [m]
    SWC
    2380.0
    [m]
    DC
    2400.0
    [m]
    DC
    2420.0
    [m]
    DC
    2440.0
    [m]
    DC
    2445.0
    [m]
    DC
    2450.0
    [m]
    DC
    2455.0
    [m]
    DC
    2460.0
    [m]
    DC
    2465.0
    [m]
    DC
    2480.0
    [m]
    DC
    2482.0
    [m]
    SWC
    2500.0
    [m]
    DC
    2512.0
    [m]
    SWC
    2520.0
    [m]
    DC
    2532.0
    [m]
    SWC
    2540.0
    [m]
    DC
    2557.0
    [m]
    SWC
    2557.0
    [m]
    SWC
    2565.0
    [m]
    DC
    2603.0
    [m]
    SWC
    2630.0
    [m]
    SWC
    2673.5
    [m]
    SWC
    2745.0
    [m]
    SWC
    2789.0
    [m]
    SWC
    2793.0
    [m]
    SWC