Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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08.02.2026 - 01:24
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25/4-6 S

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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.
    25/4-6 S
    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 top-hole drilling campaign covering several wellbores.
    RE-CLASS TO DEV: Exploration wellbore that is reclassified to a development wellbore and given a new name.
    RE-CLASS TO TEST: Exploration wellbore that is reclassified to test production and given a new name.
    SUSPENDED: The drilling operation in the wellbore has been temporarily stopped. The current plan is to continue drilling later on.
    WILL NEVER BE DRILLED: Wellbore registered with a name and WellID by the Norwegian Offshore Directorate, but which for various reasons will not be drilled.
    ONLINE/OPERATIONAL: The wellbore is ongoing, but not completed, may be operations such as drilling, batch-drilling, logging, testing, plugging, preparation for production/injection or temporarily stopped in connection with the operations.
    SUSPENDED
    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.
    25/4-6
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    EL8802 - 110 SP 205
    Drilling operator
    Name of the licensee starting the drilling operation on behalf of the active production license. This is usually 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.
    678-L
    Production licence at wellhead
    Official designation of the production licence the wellbore was drilled or planned to be drilled from (wellhead posistion).
    Prod. licence for drilling target
    The active production licence of the planned drilling target of the wellbore. This can differ from the production licence the wellbore was drilled from.
    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.
    132
    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,
    15.04.1991
    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.
    24.08.1991
    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.
    24.08.1993
    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.
    15.02.2006
    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.
    GAS/CONDENSATE
    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.
    MIDDLE JURASSIC
    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.
    HUGIN FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    22.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    114.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4170.0
    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).
    4136.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    22.5
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    143
    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.
    59° 42' 35.43'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 19' 4.45'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6619449.04
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    461620.07
    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.
    1703
    Legend +

  • Wellbore history
    General
    Well 25/4-6 S was planned to prove the hydrocarbon potential in a structure located on the northern extension of the Heimdal Ridge. The structure is located in the NE corner of block 25/4, fairly close to the Heimdal, Frøy and Frigg Fields. Four-ways closures were mapped on all levels from the "Near top Frigg sequence" marker to the Base Vestland Group Marker. The structure above the Base Cretaceous Unconformity is a fairly simple dome/mounded feature, while the Vestland Group and deeper sections consist of an antithetic tilted block. The objective of the well was to explore all closures down to at least Vestland Group level. The primary target was the Vestland Group; secondary targets were the Frigg and Heimdal Formations, while the Statfjord Formation was a third, optional target. Based on data from surrounding wells, no abnormal pressure was expected. To achieve an optimal position in reaching the targets the well was planned deviated.
    Operations and results
    Wildcat well 25/4-6 S was spudded with the semi-submersible installation West Vanguard on 15 April 1991 and drilled to TD at 4170 m, 41 m into the Statfjord Formation. The well was drilled vertical (max 2 deg deviation) through the Frigg and Heimdal prospects down to 2424 m. From here angle was built up to a maximum of 22.5 deg at 3025 m before it was dropped off again to 3 deg at final TD. The hole opener cone was lost at 266 m resulting in 8 days and 15 hours lost time before drilling could be resumed. The FMT tool got stuck at 3836 m with fishing unsuccessful. Thus it was decided to set a cement plug on top of the tool and perform a sidetrack. The well was drilled with seawater and viscous pills down to 197 m, with bentonite mud from 197 m to 1220 m, with KCl/polymer mud from 1220 m to 2503 m, and with lignosulphonate mud from 2503 m to TD.
    The Early Eocene Frigg reservoir was not found, and the Palaeocene Heimdal reservoir was water bearing. Top Vestland Group came in at a depth of 3716 m, 37 m deeper than predicted. The group was 222 m thick and hydrocarbon bearing over the uppermost 120 m (hydrocarbon/water contact at 3836 m). The reservoir fluid type was assumed to be a condensate/wet gas with a 0.486 g/cc gradient over the HC-bearing zone, according to the RFT measurements. The Statfjord Formation was water bearing.
    A total of 12 conventional cores were cut from the Vestland Group, Dunlin Group, and the Statfjord Formation. The mismatch between core depth and logger's depth was large. Core depth had to be added a correction of 8.5 m to 11 m in order to match with the logger's depth. A total of 25 sidewall cores were attempted and 19 were recovered. Two FMT fluid samples were taken, at 3803.5 m in the Hugin Formation and at 4141.5 m in the Statfjord Formation. Both recovered salt water with a small volume of gas.
    The well was suspended on 24 August 1991 as a gas/condensate discovery.
    Testing
    One DST tests was performed in the interval 3802-3819 m and flowed at a rate of 461700 Sm3/d gas and 688 Sm3/d oil through a 20.64 mm choke. The GOR was 671 Sm3/Sm3 with an oil density of 0.82 g/ml (41 deg API).

  • 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]
    210.00
    4020.00

  • 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
    3712.0
    3714.3
    [m ]
    2
    3715.0
    3733.2
    [m ]
    3
    3734.0
    3745.8
    [m ]
    4
    3746.0
    3774.0
    [m ]
    5
    3774.0
    3790.4
    [m ]
    6
    3791.0
    3818.8
    [m ]
    7
    3819.0
    3846.3
    [m ]
    8
    3846.5
    3873.0
    [m ]
    9
    3874.0
    3902.2
    [m ]
    10
    4061.0
    4070.0
    [m ]
    11
    4124.0
    4131.1
    [m ]
    12
    4131.5
    4134.0
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    205.0
    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
    1900.0
    [m]
    DC
    SNEA(P)
    1920.0
    [m]
    DC
    SNEA(P)
    1940.0
    [m]
    DC
    SNEA(P)
    1960.0
    [m]
    DC
    SNEA(P)
    1980.0
    [m]
    DC
    SNEA(P)
    2000.0
    [m]
    DC
    SNEA(P)
    2040.0
    [m]
    DC
    SNEA(P)
    2060.0
    [m]
    DC
    SNEA(P)
    2070.3
    [m]
    C
    SNEA(P)
    2080.0
    [m]
    C
    SNEA(P)
    2090.0
    [m]
    DC
    SNEA(P)
    2100.0
    [m]
    DC
    PETROSTR
    2110.0
    [m]
    DC
    PETROS
    2118.0
    [m]
    C
    SNEA(P)
    2120.0
    [m]
    DC
    PETROS
    2122.0
    [m]
    C
    SNEA(P)
    2130.0
    [m]
    DC
    PETROS
    2136.1
    [m]
    C
    SNEA(P)
    2140.0
    [m]
    C
    SNEA(P)
    2140.0
    [m]
    DC
    PETROS
    2146.5
    [m]
    C
    SNEA(P)
    2150.0
    [m]
    DC
    PETROS
    2150.5
    [m]
    C
    SNEA(P)
    2153.5
    [m]
    C
    SNEA(P)
    2160.0
    [m]
    DC
    PETROS
    2165.0
    [m]
    C
    SNEA(P)
    2170.0
    [m]
    DC
    PETROS
    2180.0
    [m]
    DC
    PETROS
    2180.0
    [m]
    DC
    HYDRO
    2190.0
    [m]
    DC
    PETROS
    2199.4
    [m]
    C
    SNEA(P)
    2200.0
    [m]
    DC
    PETROS
    2210.0
    [m]
    DC
    SNEA(P)
    2220.0
    [m]
    DC
    HYDRO
    2220.0
    [m]
    DC
    PETROS
    2230.0
    [m]
    DC
    SNEA(P)
    2240.0
    [m]
    DC
    HYDRO
    2240.0
    [m]
    DC
    PETROS
    2250.0
    [m]
    DC
    SNEA(P)
    2260.0
    [m]
    DC
    HYDRO
    2270.0
    [m]
    DC
    SNEA(P)
    2280.0
    [m]
    DC
    HYDRO
    2290.0
    [m]
    DC
    SNEA(P)
    2300.0
    [m]
    DC
    HYDRO
    2310.0
    [m]
    DC
    SNEA(P)
    2310.0
    [m]
    DC
    PETROS
    2320.0
    [m]
    DC
    HYDRO
    2329.0
    [m]
    DC
    SNEA(P)
    2330.0
    [m]
    DC
    PETROS
    2334.5
    [m]
    C
    SNEA(P)
    2340.0
    [m]
    DC
    PETROS
    2345.3
    [m]
    C
    SNEA(P)
    2350.0
    [m]
    C
    SNEA(P)
    2360.0
    [m]
    DC
    HYDRO
    2360.0
    [m]
    DC
    SNEA(P)
    2360.0
    [m]
    DC
    PETROS
    2375.4
    [m]
    C
    SNEA(P)
    2380.0
    [m]
    DC
    SNEA(P)
    2380.0
    [m]
    DC
    PETROS
    2390.0
    [m]
    DC
    PETROS
    2400.0
    [m]
    DC
    HYDRO
    2400.0
    [m]
    DC
    SNEA(P)
    2420.0
    [m]
    DC
    HYDRO
    2420.0
    [m]
    DC
    PETROS
    2440.0
    [m]
    DC
    HYDRO
    2440.0
    [m]
    DC
    SNEA(P)
    2440.0
    [m]
    DC
    PETROS
    2450.0
    [m]
    DC
    PETROS
    2460.0
    [m]
    DC
    PETROS
    2460.0
    [m]
    DC
    HYDRO
    2462.0
    [m]
    C
    SNEA(P)
    2470.3
    [m]
    C
    SNEA(P)
    2480.0
    [m]
    DC
    HYDRO
    2480.0
    [m]
    DC
    SNEA(P)
    2490.0
    [m]
    DC
    PETROS
    2500.0
    [m]
    DC
    HYDRO
    2505.0
    [m]
    DC
    SNEA(P)
    2510.0
    [m]
    DC
    PETROS
    2520.0
    [m]
    DC
    HYDRO
    2520.0
    [m]
    DC
    PETROS
    2530.0
    [m]
    DC
    PETROS
    2540.0
    [m]
    DC
    HYDRO
    2540.0
    [m]
    DC
    SNEA(P)
    2545.0
    [m]
    DC
    PETROS
    2555.0
    [m]
    DC
    PETROS
    2560.0
    [m]
    DC
    HYDRO
    2560.0
    [m]
    DC
    SNEA(P)
    2570.0
    [m]
    DC
    PETROS
    2570.3
    [m]
    C
    SNEA(P)
    2580.0
    [m]
    DC
    HYDRO
    2580.0
    [m]
    DC
    HYDRO
    2580.0
    [m]
    DC
    PETROS
    2600.0
    [m]
    DC
    HYDRO
    2600.0
    [m]
    DC
    SNEA(P)
    2610.0
    [m]
    DC
    PETROS
    2620.0
    [m]
    DC
    PETROS
    2620.0
    [m]
    DC
    SNEA(P)
    2620.0
    [m]
    DC
    SNEA(P)
    2630.0
    [m]
    DC
    PETROS
    2640.0
    [m]
    DC
    HYDRO
    2640.0
    [m]
    DC
    SNEA(P)
    2650.0
    [m]
    DC
    PETROS
    2650.0
    [m]
    DC
    PETROS
    2660.0
    [m]
    DC
    HYDRO
    2660.0
    [m]
    DC
    SNEA(P)
    2665.0
    [m]
    DC
    PETROS
    2680.0
    [m]
    DC
    HYDRO
    2680.0
    [m]
    DC
    SNEA(P)
    2685.0
    [m]
    DC
    PETROS
    2700.0
    [m]
    DC
    PETROS
    2700.0
    [m]
    DC
    HYDRO
    2700.0
    [m]
    DC
    SNEA(P)
    2715.0
    [m]
    DC
    PETROS
    2720.0
    [m]
    DC
    HYDRO
    2720.0
    [m]
    DC
    SNEA(P)
    2730.0
    [m]
    DC
    PETROS
    2740.0
    [m]
    DC
    PETROS
    2740.0
    [m]
    DC
    HYDRO
    2740.0
    [m]
    DC
    SNEA(P)
    2750.0
    [m]
    DC
    PETROS
    2760.0
    [m]
    DC
    HYDRO
    2760.0
    [m]
    DC
    SNEA(P)
    2780.0
    [m]
    DC
    HYDRO
    2910.0
    [m]
    DC
    SNEA(P)
    3055.0
    [m]
    DC
    SNEA(P)
    3150.0
    [m]
    DC
    SNEA(P)
    3270.0
    [m]
    DC
    SNEA(P)
    3395.0
    [m]
    DC
    SNEA(P)
    3530.0
    [m]
    DC
    SNEA(P)
    3565.0
    [m]
    DC
    SNEA(P)
    3580.0
    [m]
    DC
    SNEA(P)
    3600.0
    [m]
    DC
    SNEA(P)
    3620.0
    [m]
    DC
    SNEA(P)
    3640.0
    [m]
    DC
    SNEA(P)
    3650.0
    [m]
    DC
    SNEA(P)
    3660.0
    [m]
    DC
    SNEA(P)
    3680.0
    [m]
    DC
    SNEA(P)
    3700.0
    [m]
    DC
    SNEA(P)
    3710.0
    [m]
    DC
    SNEA(P)
    3712.1
    [m]
    C
    SNEA(P)
    3713.2
    [m]
    C
    SNEA(P)
    3715.5
    [m]
    C
    SNEA(P)
    3716.5
    [m]
    C
    SNEA(P)
    3717.3
    [m]
    C
    SNEA(P)
    3718.0
    [m]
    DC
    SNEA(P)
    3719.5
    [m]
    C
    SNEA(P)
    3721.0
    [m]
    DC
    SNEA(P)
    3723.0
    [m]
    DC
    SNEA(P)
    3725.5
    [m]
    C
    SNEA(P)
    3727.0
    [m]
    DC
    SNEA(P)
    3729.4
    [m]
    C
    SNEA(P)
    3731.0
    [m]
    C
    SNEA(P)
    3734.0
    [m]
    DC
    SNEA(P)
    3736.0
    [m]
    DC

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