Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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22.11.2024 - 09:09
Time of last synchronization with Norwegian Offshore Directorate's internal systems

25/1-1

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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.
    25/1-1
    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
    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.
    25/1-1
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    line 69205-SP 162
    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.
    53-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.
    115
    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,
    30.03.1971
    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.
    22.07.1971
    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.
    22.07.1973
    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.
    26.05.2009
    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
    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.
    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.
    24.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    101.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4570.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    4.2
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    98
    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.
    MIDDLE 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.
    HUGIN FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    59° 53' 17.4'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 4' 42.7'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6639470.41
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    448427.57
    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.
    190

  • Wellbore history
    General
    Well 25/1-1 was drilled in the middle of block 25/1 in the Viking Graben, close to the UK border. Seismic surveys had defined structural closure at several levels in Mesozoic and into lower Tertiary horizons. At Paleocene level an "amoeboid" feature extending as much as 350 km2 with a vertical closure of 180 m was mapped. The primary objective of the well was to test the hydrocarbon potential of the Early Tertiary, interpreted to be a deltaic sand build-up. Secondary objective was Jurassic sandstones.
    The well is Type Well for the Frigg, Svarte, Blodøks, Tryggvason, Kyrre, and Jorsalfare Formations.
    Operations and results
    Wildcat well 25/1-1 was spudded with the semi-submersible installation Pentagone 81 on 30 March 1971 and drilled to TD at 4570 m in Middle Jurassic Hugin Formation. The well was drilled with a seawater/LFC mud system down to TD.
    Apart from sandy sections in the Nordland Group, the lithology down to top Frigg Formation at 1836 m was mainly claystones. The Frigg Formation sandstones had porosities in the range 30 to 40% with permeabilities of several Darcy. It was hydrocarbon bearing with a gas/oil contact at 1972 m, and an oil/water contact at 1992 m. Further shows were seen in a thin sand at 2470 m in the Lista Formation. An FIT sample recovered a small amount of oil from this sand. Oil shows were also recorded on limestone on core K5 in the Jorsalfare Formation. The Jurassic sequence penetrated by the well was mainly shales of the Viking Group and only 10 m of Hugin Formation sand at TD. No shows were reported from the Hugin Formation.
    Six conventional cores were cut. Cores K1 to K3 were cut from 1868 to 1910 m in the Frigg Formation. K4 was cut from 2687 to 2696 m in the lower Lista Formation, while K5 and K6 were cut from 2826 to 2843 m and from 2993 m to 2997.5 m in the Jorsalfare Formation. Wire line fluid sampling was attempted at nine different depths. Hydrocarbon fluids were recovered from four levels: 1893 m (gas and filtrate), 1927.5 m (gas and filtrate), 1973.5 m (gas, filtrate and a small amount of oil), and 2471 m (filtrate and a small amount of oil).
    The well was permanently abandoned on 22 July 1971 as an oil and gas discovery.
    Testing
    A production test was carried through perforations between 1920 and 1928 m on gas bearing Frigg Formation sands. The test produced 674000 Sm3 gas /day.

  • Cuttings at the Norwegian Offshore Directorate
    Cuttings at the Norwegian Offshore Directorate
    Cuttings available for sampling?
    NO
    Cuttings at the Norwegian Offshore Directorate
    Cutting sample, top depth [m]
    Cutting samples, bottom depth [m]
    1120.00
    4558.00

  • 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
    1871.0
    1877.0
    [m ]
    2
    1891.5
    1895.0
    [m ]
    3
    1900.0
    1910.0
    [m ]
    4
    2687.0
    2696.0
    [m ]
    5
    2826.0
    2843.1
    [m ]
    6
    2993.0
    2997.5
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    50.1
    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
    1360.0
    [m]
    DC
    1370.0
    [m]
    DC
    1430.0
    [m]
    DC
    1450.0
    [m]
    DC
    1490.0
    [m]
    DC
    1500.0
    [m]
    DC
    1780.0
    [m]
    DC
    1790.0
    [m]
    DC
    1830.0
    [m]
    DC
    1840.0
    [m]
    DC
    1876.0
    [m]
    C
    IGS
    2126.0
    [m]
    DC
    2140.0
    [m]
    DC
    2225.0
    [m]
    DC
    2245.0
    [m]
    DC
    2426.0
    [m]
    DC
    2445.0
    [m]
    DC
    2465.0
    [m]
    DC
    2526.0
    [m]
    DC
    2541.0
    [m]
    DC
    2601.0
    [m]
    DC
    OD
    2622.0
    [m]
    DC
    OD
    2640.0
    [m]
    DC
    OD
    2640.0
    [m]
    DC
    2657.0
    [m]
    DC
    OD
    2665.0
    [m]
    DC
    2679.0
    [m]
    DC
    OD
    2682.0
    [m]
    DC
    2690.0
    [m]
    C
    IGS
    2691.1
    [m]
    C
    OD
    2694.7
    [m]
    C
    OD
    2695.0
    [m]
    C
    IGS
    2720.0
    [m]
    DC
    OD
    2723.0
    [m]
    DC
    2740.0
    [m]
    DC
    OD
    2760.0
    [m]
    DC
    OD
    2778.0
    [m]
    DC
    OD
    2800.0
    [m]
    DC
    OD
    2829.3
    [m]
    C
    OD
    2830.1
    [m]
    C
    OD
    2831.9
    [m]
    C
    OD
    2833.7
    [m]
    C
    OD
    2835.5
    [m]
    C
    OD
    2837.3
    [m]
    C
    OD
    2839.1
    [m]
    C
    OD
    2840.9
    [m]
    C
    OD
    2842.7
    [m]
    C
    OD
    2860.0
    [m]
    DC
    OD
    2874.0
    [m]
    DC
    OD
    2882.0
    [m]
    DC
    OD
    2993.5
    [m]
    C
    OD
    2996.2
    [m]
    C
    OD
    3012.0
    [m]
    DC
    OD
    3039.0
    [m]
    DC
    OD
    3071.0
    [m]
    DC
    OD
    3103.0
    [m]
    DC
    OD
    3146.0
    [m]
    DC
    OD
    3174.0
    [m]
    DC
    OD
    3205.0
    [m]
    DC
    OD
    3226.0
    [m]
    DC
    OD
    3250.0
    [m]
    DC
    OD
    3276.0
    [m]
    DC
    OD
    3300.0
    [m]
    DC
    OD
    3327.0
    [m]
    DC
    OD
    3351.0
    [m]
    DC
    OD
    3378.0
    [m]
    DC
    OD
    3398.0
    [m]
    DC
    OD
    3426.0
    [m]
    DC
    OD
    3449.0
    [m]
    DC
    OD
    3473.0
    [m]
    DC
    OD
    3497.0
    [m]
    DC
    OD
    3501.0
    [m]
    DC
    OD
    3525.0
    [m]
    DC
    OD
    3553.0
    [m]
    DC
    OD
    3577.0
    [m]
    DC
    OD
    3601.0
    [m]
    DC
    OD
    3625.0
    [m]
    DC
    OD
    3649.0
    [m]
    DC
    OD
    3676.0
    [m]
    DC
    OD
    3696.0
    [m]
    DC
    OD
    3731.0
    [m]
    DC
    OD
    3751.0
    [m]
    DC
    OD
    3772.0
    [m]
    DC
    OD
    3800.0
    [m]
    DC
    OD
    3828.0
    [m]
    DC
    OD
    3858.0
    [m]
    DC
    OD
    3878.0
    [m]
    DC
    OD
    3900.0
    [m]
    DC
    OD
    3924.0
    [m]
    DC
    OD
    3952.0
    [m]
    DC
    OD
    3976.0
    [m]
    DC
    OD
    3996.0
    [m]
    DC
    OD
    4024.0
    [m]
    DC
    OD
    4052.0
    [m]
    DC
    OD
    4076.0
    [m]
    DC
    OD
    4100.0
    [m]
    DC
    OD
    4124.0
    [m]
    DC
    OD
    4152.0
    [m]
    DC
    OD
    4176.0
    [m]
    DC
    OD
    4196.0
    [m]
    DC
    OD
    4228.0
    [m]
    DC
    OD
    4248.0
    [m]
    DC
    OD
    4300.0
    [m]
    DC
    OD
    4356.0
    [m]
    DC
    OD
    4404.0
    [m]
    DC
    OD
    4452.0
    [m]
    DC
    OD
    4504.0
    [m]
    DC
    OD
    4524.0
    [m]
    DC
    OD
    4558.0
    [m]
    DC
    OD

  • Oil samples at the Norwegian Offshore Directorate
    Oil samples at the Norwegian Offshore Directorate
    Test type
    Bottle number
    Top depth
    MD [m]
    Bottom depth
    MD [m]
    Fluid type
    Test time
    Samples available
    DST
    0.00
    0.00
    WATER
    06.07.1971 - 00:00
    YES

  • Lithostratigraphy

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    12.04
    pdf
    0.61
    pdf
    0.60
    pdf
    0.29

  • Documents – reported by the production licence (period for duty of secrecy expired)

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    1920
    1928
    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
    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
    674000

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    BHC GR
    459
    4453
    CBL
    350
    4063
    CBL GR
    1200
    2947
    DLL
    1835
    4140
    FDC GR
    1835
    2850
    HDT
    1835
    4059
    HRT
    1000
    2920
    IES
    460
    2100
    ML MLL
    1835
    2855
    SNP
    1835
    2850
    SRS
    459
    4453

  • 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
    LOT
    SURF.COND.
    20
    459.0
    26
    490.0
    0.00
    LOT
    INTERM.
    13 3/8
    1835.0
    17 1/2
    1846.0
    0.00
    LOT
    INTERM.
    9 5/8
    2950.0
    12 1/4
    2960.0
    0.00
    LOT
    PROD.
    7
    4062.0
    8 1/2
    4063.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    0
    1.68
    65.0
    waterbased
    490
    1.25
    65.0
    waterbased
    1846
    1.30
    60.0
    waterbased
    2371
    1.25
    44.0
    waterbased
    3195
    1.65
    56.0
    waterbased
    4029
    1.68
    65.0
    waterbased
    4455
    1.90
    60.0
    waterbased

  • 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