Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
29.04.2024 - 01:33
Time of last synchronization with Norwegian Offshore Directorate's internal systems

7132/2-1

Export: PDF icon PDF

  • General information
    General information
    Attribute Value
    Wellbore name
    Official name of wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    7132/2-1
    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
    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.
    BARENTS SEA
    Well name
    Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    7132/2-1
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    ST-14004. Inline: 5839. Xline: 15483
    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.
    Equinor Energy 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.
    1740-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.
    16
    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,
    01.01.2019
    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.
    09.02.2019
    Plugged and abondon date
    Date when the P&A-operations of the wellbore was finished, as reported by the operator to the Norwegian Offshore Directorate throught DDRS (Daily Drilling Reporting System). Only applied once pr. wellhead/surface location.
    09.02.2019
    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.
    01.07.2020
    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.
    03.05.2021
    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.
    31.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    293.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    883.0
    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).
    883.0
    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.
    LATE 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.
    SNADD FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    71° 51' 55.88'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    32° 25' 56.4'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7974242.39
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    480278.88
    UTM zone
    Universal Transverse Mercator zone. Examples of legal values: 31, 32, 33, 34.
    36
    NPDID wellbore
    Norwegian Offshore Directorate's unique id for the wellbore.
    8629

  • Wellbore history
    General
    Well 7132/2-1 was drilled to test the Gjøkåsen prospect on the Signalhornet Dome on the Finmark Platform in the Barents Sea. This part of the Barents Sea is a frontier exploration area, the nearest offset well is approximately 60 km away. The Gjøkåsen prospect is located approximately 55 km West of the Russian border and 150 km North of the coast of Norway. The primary exploration target for the well was to prove petroleum in reservoir rocks from the Middle and Early Jurassic Age (the Stø, Nordmela, Tubåen and Fruholmen formation). The secondary exploration target was reservoir rocks from the Early Cretaceous and Late Triassic Age (upper part of the Snadd formation).
    Operations and results
    A pilot well 7132/2-U-1was spudded on the 30th of December 2018 and drilled to 601.4m MD (600.3m TVD RKB) within the Kolmule Formation. The pilot well confirmed that no shallow gas or reservoirs were present, and that the main well would have the required operational safety margins to drill as planned.
    Wildcat well 7132/2-1 was spudded with the semi-submersible installation West Hercules on 1 January 2019 and drilled to TD at 883 m in the Late Triassic Snadd Formation. The top holes on 7132/2-1 and the nearby 7132/2-2 were batch drilled for more efficient operations and save time on running BOP. Hence, operations on 7132/2-1 was suspended at 600 m between 5 and 14 January before drilling could commence with the 12 ¼” section. Operations proceeded without significant problems. The well was drilled with seawater down to 600 m and with KCl/Polymer/GEM mud from 600 m to TD.
    In the primary exploration target, well 7132/2-1 encountered about 8 metres of sandstone reservoir with good reservoir quality in the Stø Formation. In the Nordmela, Tubåen and Fruholmen formations, the well encountered about 32 metres of sandstone reservoir with good to very good reservoir quality.  No reservoir rocks were encountered in the secondary exploration target in the Early Cretaceous. In the upper part of the Snadd formation, the well encountered a water-filled sandstone reservoir totalling about 30 metres with moderate to good reservoir quality. The well was dry without oil shows on cuttings or core. The highest gas value was measured at 660m MD, with 1.34%, from the top Hekkingen Formation.
    One core was cut from 705 to 722.8 m with 12.47 m recovery (70.1%) in the Stø and Nordmela formations. 10 good XPT pressure points were acquired, but no fluid sample was taken. Maximum pore pressure was 84.07 bar (1.04 g/cc) at 824.5 m.
    The well was permanently abandoned on 9 February 2019 as a dry well.
    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]
    603.00
    883.00

  • 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
    705.0
    717.5
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    12.5
    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
    603.0
    [m]
    DC
    CGG
    609.0
    [m]
    DC
    CGG
    615.0
    [m]
    DC
    CGG
    621.0
    [m]
    DC
    CGG
    627.0
    [m]
    DC
    CGG
    633.0
    [m]
    DC
    CGG
    639.0
    [m]
    DC
    CGG
    645.0
    [m]
    DC
    CGG
    651.0
    [m]
    DC
    CGG
    657.0
    [m]
    DC
    CGG
    660.0
    [m]
    DC
    CGG
    663.0
    [m]
    DC
    CGG
    669.0
    [m]
    DC
    CGG
    673.0
    [m]
    DC
    CGG
    679.0
    [m]
    DC
    CGG
    685.0
    [m]
    DC
    CGG
    688.0
    [m]
    DC
    CGG
    691.0
    [m]
    DC
    CGG
    694.0
    [m]
    DC
    CGG
    697.0
    [m]
    DC
    CGG
    700.0
    [m]
    DC
    CGG
    703.0
    [m]
    DC
    CGG
    706.0
    [m]
    DC
    CGG
    707.5
    [m]
    C
    CGG
    709.8
    [m]
    C
    CGG
    711.3
    [m]
    C
    CGG
    715.5
    [m]
    C
    CGG
    717.4
    [m]
    C
    CGG
    724.0
    [m]
    DC
    CGG
    727.0
    [m]
    DC
    CGG
    730.0
    [m]
    DC
    CGG
    736.0
    [m]
    DC
    CGG
    742.0
    [m]
    DC
    CGG
    748.0
    [m]
    DC
    CGG
    754.0
    [m]
    DC
    CGG
    760.0
    [m]
    DC
    CGG
    766.0
    [m]
    DC
    CGG
    772.0
    [m]
    DC
    CGG
    778.0
    [m]
    DC
    CGG
    784.0
    [m]
    DC
    CGG
    790.0
    [m]
    DC
    CGG
    796.0
    [m]
    DC
    CGG
    802.0
    [m]
    DC
    CGG
    808.0
    [m]
    DC
    CGG
    814.0
    [m]
    DC
    CGG
    820.0
    [m]
    DC
    CGG
    826.0
    [m]
    DC
    CGG
    832.0
    [m]
    DC
    CGG
    838.0
    [m]
    DC
    CGG
    844.0
    [m]
    DC
    CGG
    850.0
    [m]
    DC
    CGG
    856.0
    [m]
    DC
    CGG
    862.0
    [m]
    DC
    CGG
    868.0
    [m]
    DC
    CGG
    874.0
    [m]
    DC
    CGG
    880.0
    [m]
    DC
    CGG
    883.0
    [m]
    DC
    CGG

  • Lithostratigraphy

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    HRLA HNGS ECS PEX
    670
    883
    MDT CMR
    670
    883
    MSIP FMI
    306
    883
    MWD LWD - ARC TELE
    377
    600
    MWD LWD - GVR ARC TELE
    671
    705
    MWD LWD - GVR ARC TELE
    722
    883
    MWD LWD - GVR ARC TELE ADNVIS
    600
    671
    MWD LWD - TELE 900
    324
    377
    VSI4
    306
    883
    XLR
    676
    767
    XLR
    676
    676

  • 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
    36
    373.9
    42
    374.0
    0.00
    INTERM.
    13 3/8
    595.0
    17 1/2
    600.0
    1.40
    FIT
    INTERM.
    9 5/8
    670.0
    12 1/4
    671.0
    1.54
    FIT
    OPEN HOLE
    833.0
    8 1/2
    833.0
    0.00

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    378
    1.20
    18.0
    KCl/Polymer/GEM
    600
    1.35
    25.0
    KCl/Polymer/GEM
    600
    1.14
    15.0
    KCl/Polymer/GEM
    671
    1.16
    15.0
    KCl/Polymer/GEM
    671
    1.21
    16.0
    KCl/Polymer/GEM
    705
    1.21
    17.0
    KCl/Polymer/GEM
    883
    1.21
    18.0
    KCl/Polymer/GEM