Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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22.12.2024 - 01:25
Time of last synchronization with Norwegian Offshore Directorate's internal systems

25/2-7

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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.
    25/2-7
    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
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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
    Well name
    Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    25/2-7
    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.
    321-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.
    103
    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,
    01.04.1982
    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.
    12.07.1982
    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.
    12.07.1984
    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
    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.
    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.
    25.0
    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).
    4110.0
    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).
    4110.0
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    133
    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.
    DUNLIN GP
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    59° 54' 20.41'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 38' 25.87'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6641115.53
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    479891.01
    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.
    47

  • Wellbore history
    General Block 25/2 is located on the eastern margin of the Viking Graben towards the Bjørgvin Arch. The main targets for well 25/2-7 were the Middle Jurassic Vestland Group and the Early Jurassic Statfjord Formation, which were hydrocarbon bearing in the surrounding wells 25/2-4, 25/2-5 and 25/2-6. In addition possible Late Callovian sands, as in the 25/2 -4 well, constituted a second target.
    Operations and result
    Wildcat well 25/2-7 was spudded with the semi-submersible installation Borgsten Dolphin on 1 April 1982 and drilled to TD at 4110 m in the Early Jurassic Dunlin Group. Operations took 103 days including 13 days of down time. Four and a half days were lost due to WOW, 5.5 days due to rig compensator damage, and 3 days were lost due to a leaking pack off assembly in the 9 5/8" casing. No Callovian sands (Intra Heather Formation) were encountered. Of the two main objectives the Vestland Group was confirmed and tested as a reservoir. The Vestland Group sandstones were encountered at 3406 m, 174 m higher than prognosed. It was 389 m thick, which was thicker than expected, and it consisted of an upper and a lower interval. Massive beds of sandstone, locally slightly shaly or well cemented with some layers of black shales and coal were encountered in the upper interval from 3406 m to 3628 m. The gross thickness of this interval was 222 m and net thickness approximately 179 m. Porosity as estimated from cores 1 and 2 and logs ranged from 2.5 % to 21 % with an average of 12 %. Permeability in this zone was rather low (0.01 to 15.55 mD). The second zone was penetrated from 3628 m to 3795 m. This interval was composed of shales and sandstones alternating in a regular sequences of 15 to 20 m. Net thickness was approximately 77 m with a porosity ranging from 16 % to 21% based on logs. Some oil shows were recorded on cores 1 and 2 in the upper Vestland sand interval. They must be considered as residual shows as the reservoir is water bearing according to the logs. The RFT results confirmed this, showing a hydrostatic pressure gradient. Sandstones of the Statfjord Formation was not found. A silty/shaley interval at 3870 m, 198 m thick, was thought to be an equivalent of them, according to log correlation with the 25/2-5 well, but this was not supported by biostratigraphic data. Due to lack of seismic information at this level there was no incitement to drill deeper. A yellow direct florescence cut was observed on cuttings from this interval from 3917 m to 3920 m. Four conventional cores were cut in the well. Two were cut in the interval 3409 m to 3444 m in the Vestland Group (Sandstone with coals), two were cut in the Dunlin Group. Of the latter one was cut in shale from 3791 m to 3799 m and the other was cut at TD in red brown shale. One RFT fluid sample was taken at 3436.7 m (filtrate, formation water, and traces of oil), another at 3410 m (filtrate and formation water). The well was permanently abandoned on 12 July 1982 as a well with shows.
    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]
    220.00
    4102.00

  • 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
    3409.0
    3414.0
    [m ]
    2
    3424.5
    3443.5
    [m ]
    3
    3791.0
    3798.0
    [m ]
    4
    4101.0
    4110.0
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    40.0
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 3409-3414m
    Core photo at depth: 3424-3429m
    Core photo at depth: 3429-3434m
    Core photo at depth: 3434-3439m
    Core photo at depth: 3439-3792m
    3409-3414m
    3424-3429m
    3429-3434m
    3434-3439m
    3439-3792m
    Core photo at depth: 3792-3797m
    Core photo at depth: 3797-4109m
    Core photo at depth: 4109-4114m
    Core photo at depth:  
    Core photo at depth:  
    3792-3797m
    3797-4109m
    4109-4114m

  • 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
    201.0
    36
    203.0
    0.00
    LOT
    SURF.COND.
    20
    727.0
    26
    739.0
    1.06
    LOT
    INTERM.
    13 3/8
    2194.5
    17 1/2
    2210.0
    1.17
    LOT
    INTERM.
    9 5/8
    3275.0
    12 1/4
    3290.0
    1.27
    LOT
    OPEN HOLE
    4110.0
    8 1/2
    4110.0
    0.00
    LOT

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    BGT
    727
    2182
    BHC GR
    2198
    3180
    CBL VDL
    300
    2198
    CBL VDL
    1800
    3279
    CIS
    2198
    3285
    CIS
    3279
    4084
    CST
    2162
    2183
    CST
    2345
    3280
    CST
    3380
    4080
    DLL MSFL
    3350
    3630
    HDT
    2198
    3285
    HDT
    3279
    4084
    ISF GR BHC SL
    138
    4097
    LDT CNL GR CAL
    201
    4088
    NGST
    3279
    4077
    RFT
    3408
    3591
    VELOCITY
    138
    4097

  • Lithostratigraphy

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    1.75

  • 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
    9.97

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    210
    1.09
    spud mud
    540
    1.11
    water based
    790
    1.06
    water based
    1640
    1.22
    water based
    2210
    1.17
    water based
    2990
    1.23
    water based
    3240
    1.27
    water based
    3635
    1.21
    water based

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    2450.0
    [m]
    SWC
    SNEA
    2550.0
    [m]
    SWC
    SNEA
    2789.0
    [m]
    SWC
    SNEA
    2850.0
    [m]
    SWC
    SNEA
    3050.0
    [m]
    SWC
    SNEA
    3135.0
    [m]
    SWC
    SNEA
    3150.0
    [m]
    SWC
    SNEA
    3220.0
    [m]
    SWC
    SNEA
    3265.0
    [m]
    SWC
    SNEA
    3270.0
    [m]
    SWC
    SNEA
    3275.0
    [m]
    SWC
    SNEA
    3380.0
    [m]
    SWC
    SNEA
    3398.0
    [m]
    SWC
    SNEA
    3409.0
    [m]
    C
    SPT
    3410.0
    [m]
    C
    SPT
    3412.0
    [m]
    C
    SNEA
    3413.5
    [m]
    C
    SPT
    3426.2
    [m]
    C
    SPT
    3427.3
    [m]
    C
    SNEA
    3428.6
    [m]
    C
    SPT
    3430.6
    [m]
    C
    SPT
    3431.5
    [m]
    C
    SNEA
    3434.3
    [m]
    C
    SPT
    3435.0
    [m]
    C
    SNEA
    3439.3
    [m]
    C
    SPT
    3630.0
    [m]
    SWC
    SNEA
    3701.0
    [m]
    SWC
    SNEA
    3791.1
    [m]
    C
    SPT
    3795.5
    [m]
    C
    SPT
    3797.6
    [m]
    C
    SPT
    3798.5
    [m]
    C
    SNEA
    4101.4
    [m]
    C
    OD
    4103.3
    [m]
    C
    OD
    4106.2
    [m]
    C
    OD
    4109.0
    [m]
    C
    OD