Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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25.11.2024 - 01:30
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31/4-4

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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.
    31/4-4
    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
    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
    Well name
    Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    31/4-4
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    X 954459 + 954235.
    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.
    Norsk Hydro Produksjon 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.
    267-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.
    63
    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,
    17.12.1980
    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.
    17.02.1981
    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.
    17.02.1983
    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.
    07.11.2005
    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.
    DRY
    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.
    25.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    214.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3150.0
    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).
    3150.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    1
    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.
    EARLY 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.
    STATFJORD GP
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    60° 40' 1.12'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    3° 6' 54.12'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6725858.96
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    506287.02
    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.
    214

  • Wellbore history
    General
    Wildcat well 31/4-4 is located on the Lomre Terrace north of the Brage Field and east of the Oseberg Field. The primary objective of the well was to test possible sandstone reservoirs of Cretaceous age. The secondary objective was to test sandstone reservoirs of Late Jurassic age, anticipated to be Intra Heather Formation sands.
    The well is Reference Well for the Etive, Ness, and Tarbert Formations of the Brent Group.
    Operations and results
    Well 31/4-4 was spudded with the semi-submersible installation Nortrym on 17 December 1980 and drilled to TD at 3150 m in Early Jurassic sediments of the Statfjord Formation. The well was drilled with seawater and viscous gel down to 900 m and with KCl / polymer mud from 900 m to TD.
    No reservoir sands of Cretaceous age were encountered in the well. Poor shows were reported from two limestone stringers and a thin, tight sandstone stringer of Late Cretaceous (Maastrichtian and Late Campanian) age. A Late Jurassic "Intra Heather Sand I" (Sognefjord Formation) was encountered at 2363 m with a gross thickness of 39 m. The net sand interval was 24 m and consisted of fine-grained to very fine-grained argillaceous, micaceous sandstone. Average porosity was calculated to 16 %. Eighty-nine percent water saturation was calculated for this sand indicating that poor oil shows encountered while drilling the interval, were residual. A second "Intra Heather Sand II" (Fensfjord Formation) was penetrated at 2482 m with a gross thickness of 45 m. The sand was water bearing without shows. The lithology was similar to the upper sand. The other reservoir sequences encountered in the well, sandstones in the Middle Jurassic Brent Formation, the Early Jurassic Cook Formation, and the Statfjord Formation, were also water bearing. The gross sand thicknesses of these were 118 m, 21m and 67m, respectively.
    A single conventional core was cut between 2490m and 250 8m, near the top of the lower Intra Heather Sand interval. It was dated to Oxfordian in age and consisted of 18 m (100%) of very fine-grained sandstone with good porosity, except in some heavily cemented horizons. No fluid sample was taken.
    The well was permanently abandoned on 17 February 1981 as a dry hole.
    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]
    350.00
    3150.00

  • 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
    2490.0
    2508.0
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    18.0
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 2490-2492m
    Core photo at depth: 2492-2495m
    Core photo at depth: 2495-2498m
    Core photo at depth: 2498-2500m
    Core photo at depth: 2500-2503m
    2490-2492m
    2492-2495m
    2495-2498m
    2498-2500m
    2500-2503m
    Core photo at depth: 2503-2506m
    Core photo at depth: 2506-2508m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    2503-2506m
    2506-2508m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    740.0
    [m]
    DC
    760.0
    [m]
    DC
    790.0
    [m]
    DC
    820.0
    [m]
    DC
    850.0
    [m]
    DC
    880.0
    [m]
    DC
    910.0
    [m]
    DC
    940.0
    [m]
    DC
    970.0
    [m]
    DC
    1000.0
    [m]
    DC
    1030.0
    [m]
    DC
    1060.0
    [m]
    DC
    1090.0
    [m]
    DC
    1120.0
    [m]
    DC
    1150.0
    [m]
    DC
    1180.0
    [m]
    DC
    1210.0
    [m]
    DC
    1240.0
    [m]
    DC
    1270.0
    [m]
    DC
    1300.0
    [m]
    DC
    1330.0
    [m]
    DC
    1360.0
    [m]
    DC
    1390.0
    [m]
    DC
    1420.0
    [m]
    DC
    1450.0
    [m]
    DC
    1480.0
    [m]
    DC
    1510.0
    [m]
    DC
    1540.0
    [m]
    DC
    1570.0
    [m]
    DC
    1600.0
    [m]
    DC
    1630.0
    [m]
    DC
    1660.0
    [m]
    DC
    1690.0
    [m]
    DC
    1720.0
    [m]
    DC
    1720.0
    [m]
    DC
    1750.0
    [m]
    DC
    1780.0
    [m]
    DC
    1810.0
    [m]
    DC
    1840.0
    [m]
    DC
    1870.0
    [m]
    DC
    1900.0
    [m]
    DC
    1910.0
    [m]
    DC
    1930.0
    [m]
    DC
    1945.0
    [m]
    DC
    1960.0
    [m]
    DC
    1970.0
    [m]
    DC
    1980.0
    [m]
    DC
    1990.0
    [m]
    DC
    2000.0
    [m]
    DC
    2020.0
    [m]
    DC
    2040.0
    [m]
    DC
    2050.0
    [m]
    DC
    2080.0
    [m]
    DC
    2100.0
    [m]
    DC
    2115.0
    [m]
    DC
    2130.0
    [m]
    DC
    2150.0
    [m]
    DC
    2160.0
    [m]
    DC
    2175.0
    [m]
    DC
    2190.0
    [m]
    DC
    2200.0
    [m]
    DC
    2213.0
    [m]
    SWC
    IKU
    2216.0
    [m]
    SWC
    IKU
    2220.0
    [m]
    DC
    2227.0
    [m]
    DC
    2250.0
    [m]
    DC
    2255.0
    [m]
    DC
    2280.0
    [m]
    DC
    2280.0
    [m]
    C
    IKU
    2285.0
    [m]
    DC
    PETROSTR
    2287.0
    [m]
    DC
    PETROS
    2290.0
    [m]
    DC
    PETROS
    2295.0
    [m]
    DC
    PETROS
    2300.0
    [m]
    DC
    2302.0
    [m]
    DC
    PETROS
    2305.0
    [m]
    C
    IKU
    2312.0
    [m]
    DC
    PETROSTR
    2317.0
    [m]
    DC
    PETROS
    2325.0
    [m]
    DC
    PETROS
    2330.0
    [m]
    DC
    PETROS
    2330.0
    [m]
    C
    IKU
    2335.0
    [m]
    DC
    PETROSTR
    2352.0
    [m]
    DC
    PETROSTR
    2357.0
    [m]
    DC
    PETROS
    2362.0
    [m]
    DC
    PETROS
    2364.0
    [m]
    SWC
    IKU
    2365.0
    [m]
    DC
    PETROSTR
    2367.0
    [m]
    DC
    PETROS
    2382.0
    [m]
    DC
    PETROS
    2382.0
    [m]
    SWC
    IKU
    2385.0
    [m]
    DC
    PETROSTR
    2387.0
    [m]
    DC
    PETROS
    2410.0
    [m]
    SWC
    IKU
    2480.0
    [m]
    SWC
    IKU
    2484.9
    [m]
    SWC
    IKU
    2489.6
    [m]
    C
    IKU
    2493.5
    [m]
    C
    IKU
    2498.0
    [m]
    C
    IKU
    2502.5
    [m]
    C
    IKU
    2506.8
    [m]
    C
    IKU
    2507.7
    [m]
    C
    IKU
    2522.9
    [m]
    SWC
    IKU
    2528.9
    [m]
    SWC
    IKU
    2577.0
    [m]
    SWC
    IKU
    2628.0
    [m]
    SWC
    IKU
    2667.0
    [m]
    SWC
    IKU
    2697.0
    [m]
    SWC
    IKU
    2716.0
    [m]
    SWC
    IKU
    2767.0
    [m]
    SWC
    IKU
    2785.9
    [m]
    SWC
    IKU
    2788.6
    [m]
    SWC
    IKU
    2830.0
    [m]
    SWC
    IKU
    2851.0
    [m]
    SWC
    IKU
    2855.0
    [m]
    SWC
    IKU
    2959.0
    [m]
    SWC
    IKU
    2986.0
    [m]
    SWC
    IKU
    3022.0
    [m]
    SWC
    IKU
    3040.0
    [m]
    SWC
    IKU
    3060.0
    [m]
    SWC
    IKU
    3080.0
    [m]
    SWC
    IKU
    3136.0
    [m]
    SWC
    IKU
    3152.0
    [m]
    SWC
    IKU

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.49

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.53
    pdf
    1.70

  • 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
    12.43
    pdf
    2.24

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CST
    2060
    2410
    CST
    2066
    2735
    CST
    2480
    3152
    FDC CNL GR CAL
    1909
    3153
    FDC GR CAL
    886
    1908
    HDT
    2000
    3153
    ISF BHC GR SP
    324
    3152
    RFT
    2366
    3147
    VELOCITY
    800
    3140

  • 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
    324.0
    36
    325.0
    0.00
    LOT
    SURF.COND.
    20
    886.0
    26
    900.0
    1.60
    LOT
    INTERM.
    13 3/8
    1481.0
    17 1/2
    1918.0
    1.60
    LOT
    OPEN HOLE
    3152.0
    12 1/4
    3152.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    325
    1.04
    100.0
    seawater
    900
    1.11
    39.0
    seawater
    1918
    1.40
    53.0
    18.0
    seawater
    2490
    1.30
    57.0
    17.0
    seawater
    3150
    1.30
    61.0
    22.0
    seawater

  • 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