Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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07.11.2024 - 01:26
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25/2-18 A

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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.
    25/2-18 A
    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
    Press release
    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.
    25/2-18
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    DN13303-04010. SP 1295 / DN13303-02005. SP 1214
    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.
    Det norske oljeselskap ASA
    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.
    1638-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.
    39
    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,
    11.09.2016
    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.
    19.10.2016
    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.
    19.10.2018
    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.
    19.10.2018
    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.
    APPRAISAL
    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
    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
    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.
    55.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    121.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4066.0
    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).
    3723.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    42.2
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    125
    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.
    DRAKE FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    59° 49' 30.11'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 37' 54.1'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6632137.57
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    479347.43
    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.
    8043
  • Wellbore history

    General
    Well 25/2-18 A is a geological sidetrack to 25/2-18 S, located on the Bjørgvin Arch, four kilometers south of the 25/2-10 S (Frigg Gamma Delta) oil/gas discovery and eight kilometers north of the Frøy field in the North Sea . The 25/2-18 S well discovered oil in the Middle Jurassic Hugin Formation, the Langfjellet prospect. The target for well 25/2-18 A was southeast of 25/2-18 S but within the same segment. The objectives for sidetrack 25/2-18 A was to confirm hydrocarbons in the Hugin and Sleipner formations and to perform a drill stem test (DST).
    Operations and results
    Appraisal well 25/2-18 A was kicked off from the main bore below the 13 3/8'' casing shoe at 1555 m. It was drilled with the jack-up installation Mærsk Interceptor to TD at 4066 m (3723 m TVD) m in the Early Jurassic Drake Formation. No significant problem was encountered in the operations. The well was drilled with Versatec oil based mud from kick-off to TD.
    The Hugin Formation came in at 3698 m (3361 m TVD) and the Sleipner Formation came in at 3825.5 m (3486.3 m TVD). The well proved oil proved in the Hugin Formation with an “oil down to” contact at approximately 3768 m (3430 m TVD). A total of 63 m gross reservoir thickness with 53 m net reservoir distributed across two separate compartments was recorded. No shows were recorded on cuttings due to flushing by OBM. No significant change was observed in shows on sidewall cores going from an oil zone to water zone, indicating that also sidewall cores are flushed and shows masked by OBM.
    No conventional cores were cut. A total of 17 MDT samples were acquired: 3 oil samples at 3701.5 m, 4 oil samples at 3715.4 m, 3 oil samples at 3742.2 m, 3 oil samples at 3765.8 m, 1 water sample at 3776.3 m, and 3 water samples at 3789.3 m.
    The well was plugged back for sidetracking on 19 October. It is classified as an oil appraisal well.
    Testing
    Two drill stem tests were conducted in the Hugin Formation.
    DST 1 tested the interval 3741.5 to 3767.1 m. It produced 600 Sm3 oil and 86413 sm3 gas /day through a 40/64" choke. The gas contained 3.5 ppm H2S and 4% CO2. The GOR was 144 Sm3/Sm3. Maximum flowing temperature was 115.8 °C.
    DST2 tested the interval 3713.7 to 3724.9 m. It produced 349 Sm3 oil and 51624 sm3 gas /day through a 32/64" choke. The gas contained 3.5 ppm H2S and 4% CO2. The GOR was 149 Sm3/Sm3. Maximum flowing temperature was 115.0 °C.
  • 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]
    1560.00
    4066.00
  • Lithostratigraphy

  • Drill stem tests (DST)

    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    3742
    3767
    15.8
    2.0
    3714
    3725
    12.7
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    2.0
    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
    600
    86413
    144
    2.0
    349
    51624
    149
  • Logs

    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    LWD - DI RES GR NEU DEN SON
    1555
    4066
    MDT MINIDST TT
    3701
    3792
    MSCT GR
    3694
    4035
    PP LITHOS MAGN RES
    3699
    4044
    RES SON DEN NEU SP GR
    3675
    4055
  • 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
    222.0
    36
    214.0
    0.00
    SURF.COND.
    20
    444.5
    26
    450.0
    1.32
    LOT
    PILOT HOLE
    450.0
    9 7/8
    450.0
    0.00
    SURF.COND.
    13 3/8
    1533.5
    16
    1541.0
    1.58
    FIT
    INTERM.
    9 5/8
    3680.0
    12 1/4
    3685.0
    1.88
    LOT
    LINER
    7
    4050.0
    8 1/2
    0.0
    0.00
    OPEN HOLE
    4066.0
    8 1/2
    4066.0
    0.00
  • Drilling mud

    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    1533
    1.40
    32.0
    Versatec
    2064
    1.37
    28.0
    Versatec OBM
    2900
    1.40
    30.0
    NaCl brine
    2967
    1.37
    29.0
    Versatec OBM
    3685
    1.17
    21.0
    Versatec OBM
    3685
    1.40
    29.0
    Versatec OBM
    4066
    1.17
    21.0
    Versatec OBM