Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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05.11.2024 - 01:27
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25/2-6

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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.
    25/2-6
    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
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    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.
    25/2-6
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    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.
    180-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.
    107
    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,
    01.08.1977
    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.
    15.11.1977
    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.
    15.11.1979
    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.
    01.12.2004
    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
    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 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.
    24.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    117.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3750.0
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    104
    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.
    TRIASSIC
    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.
    SMITH BANK FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    59° 45' 33.55'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 33' 5.96'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6624847.15
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    474809.83
    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.
    358

  • Wellbore history
    General
    Exploration well 25/2-6 was located in the Viking Graben on the same main structure as well 25/2-5 targeting the Jurassic were oil bearing, while the Statfjord sands gave good oil shows. 25/2-6 was drilled on the northwestern flank of a structure that was about ten years later discovered as the Frøy Field.
    The well is Type Well for the Hermod Formation.
    Operations and results
    The well was spudded with the semi-submersible installation Polyglomar Driller on 1 August 1977 and drilled to TD at 3750 m in the Triassic Smith Bank Formation.
    The well penetrated two Paleocene sands, the Hermod Formation from 2221 m to 2361 m and the Ty Formation from 2563 m to 2631 m. No shows were recorded in these sands. The Jurassic contained two major sandy but somewhat heterolithic sequences in the Vestland Group and Statfjord Formation.
    Four conventional cores were cut in the well, one from 3159.6 m to 3165 m in the Heather Formation, two from 3253.4 m to 3271.8 m in the Hugin and Sleipner formations, and one from 3509 .7 m to 3518.9 m in the Statfjord Formation. Good oil shows were recorded on the lower part of the Statfjord core. An extensive pressure and fluid sampling programme was carried out in the Jurassic with 19 RFT samples from the interval 3242.5 m in the Vestland Group and 24 RFT samples and four FIT samples from the interval 3505.1 m to 3648 m in the Statfjord Formation. Fluid samples were taken from four depths in the Sleipner and Hugin formations (3243.3 m, 3257.8 m, 3267.5 m, and 3286 m). Only one of the samples (3286 m) recovered fluid that was representative for the formation and this sample contained water with dissolved gas. In the Statfjord Formation Test No. 28 at 3563 m recovered after 7 minutes 2 litres of oil, 7 litres of gas, and 1.5 litres of emulsion. Test No. 38 at 3568,3 m recovered 0,35 litres of oil, 110 litres of gas, and 2,65 litres of mud and filtrate. From the test results, the log analysis, and fluorescence on sidewall cores, the Statfjord formation was found oil-bearing in a good sand interval from 3559 m to 3571 m.
    The well was permanently abandoned on 15 November 1977 as an appraisal well for the Lille Frøy Discovery and with minor oil in the Statfjord formation.
    Testing
    No drill stem test was performed.

  • 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]
    200.00
    3756.00

  • 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
    3159.6
    3165.1
    [m ]
    2
    3253.4
    3262.4
    [m ]
    3
    3262.4
    3271.8
    [m ]
    4
    3509.7
    3518.7
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    32.9
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • 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
    RFT
    3561.00
    0.00
    WATER
    NO
    RFT
    3267.00
    0.00
    WATER
    YES

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.43

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.82
    PDF
    0.13
    PDF
    4.92

  • 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
    48.39
    PDF
    5.04
    pdf
    14.67
    pdf
    2.84

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    BHC GR
    2824
    3104
    BHC GR
    3000
    3135
    BHC GR
    3128
    3218
    BHC GR ISF
    3128
    3356
    BHC GR ISF
    3325
    3542
    CAL
    3128
    3750
    CBL
    516
    847
    CBL
    1575
    2824
    CBL
    2450
    3144
    CBL
    2589
    3201
    DLL MSFL
    3225
    3745
    FDC GR CNL
    3127
    3356
    GR SPEC
    3128
    3750
    HDT
    742
    3747
    ID
    742
    2834
    ID
    750
    4625
    ISF
    2825
    3135
    ISF
    3128
    3799
    ISF SL GR
    141
    712
    VELOCITY
    0
    0

  • 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
    190.0
    36
    190.0
    0.00
    LOT
    SURF.COND.
    20
    750.0
    26
    750.0
    0.00
    LOT
    INTERM.
    13 3/8
    2824.0
    17 1/2
    2839.0
    0.00
    LOT
    INTERM.
    9 5/8
    3126.0
    12 1/4
    3135.0
    0.00
    LOT
    OPEN HOLE
    3750.0
    8 1/2
    3750.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    190
    1.07
    spud mud
    712
    1.07
    60.0
    water based
    1858
    1.16
    37.0
    water based
    2839
    1.25
    45.0
    water based
    3071
    1.30
    58.0
    water based
    3750
    1.35
    55.0
    water based

  • 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
    0.23