Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
22.12.2024 - 01:25
Time of last synchronization with Norwegian Offshore Directorate's internal systems

7132/2-2

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.
    7132/2-2
    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.
    7132/2-2
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    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.
    1743-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,
    06.01.2019
    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.
    07.04.2019
    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.
    07.04.2019
    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.
    304.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3528.0
    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).
    3527.0
    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 PERMIAN
    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.
    RØYE FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    71° 50' 28.37'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    32° 23' 17.84'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7971546.00
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    478721.28
    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.
    8638

  • Wellbore history
    General
    Well 7132/2-2 was drilled to test the Gjøkåsen Deep prospect on the Signalhornet Dome on the Finmark Platform in the Barents Sea. The Gjøkåsen Deep is the second well on the structure; it was planned and drilled back-to-back with the first well, 7132/2-1 Gjøkåsen. The primary exploration target for Gjøkåsen Deep was to prove petroleum in reservoir rocks from the Early to Late Triassic Age (the Snadd, Kobbe and Havert formation). The secondary exploration target was to prove petroleum and reservoir potential in the lower Havert formation (Early Triassic Age).
    Operations and results
    Wildcat well 7132/2-2 was spudded with the semi-submersible installation West Hercules on 6 January 2019 and drilled to TD at 3528 m in the Permian Røye Formation. After drilling the top hole to 600 m the well was suspended from 14 January to 9 February when the rig was engaged in operations at 7132/2-1. An influx was registered by high gas readings at surface while circulating bottoms up from TD at 3400 m, with a gas peak of 52.3% before the well was shut in. No volume increase was observed in the active system. The well was drilled with seawater and hi-vis sweeps down to 601 m, with KCl/polymer/GEM mud from 601 to 1851 m, and with Innovert oil-based mud from 1851 m to TD.
    In the primary exploration target, well 7132/2-2 encountered 25 metres of sandstone reservoir with moderate to good quality in the Snadd formation (Carnian Age), 17 metres of sandstone reservoir with poor to moderate quality in the Kobbe formation and 26 metres of sandstone reservoir with poor quality in the upper Havert formation. Sandstone reservoir was also encountered in the Klappmyss Formation (Early Triassic Age) in a thickness of 17 metres with poor quality. In the secondary exploration target in the lower Havert Formation, the well encountered an interval of approximately 110 metres of sandstones with very poor reservoir quality. High measurements of formation gas with heavier hydrocarbons in the interval 3215 to 3400 m in Havert led to an extension of the well. The objective of the extension was to evaluate potential presence of source rock and underlying reservoir rocks in the Early Triassic and Late Permian (the Ørret and Røye formation). No reservoir rocks were encountered in this interval. The well is dry. Direct fluorescence (no cut, no residue) at several levels in the well was interpreted as mineral fluorescence.
    No cores were cut. MDT water samples were taken at 1915.5 m in the Havert Formation. The samples were contaminated with 42% to 71% oil-based mud.
    The well was permanently abandoned on 7 April 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
    3393.00

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    606.0
    [m]
    DC
    CGG
    615.0
    [m]
    DC
    CGG
    624.0
    [m]
    DC
    CGG
    633.0
    [m]
    DC
    CGG
    642.0
    [m]
    DC
    CGG
    651.0
    [m]
    DC
    CGG
    660.0
    [m]
    DC
    CGG
    669.0
    [m]
    DC
    CGG
    678.0
    [m]
    DC
    CGG
    687.0
    [m]
    DC
    CGG
    696.0
    [m]
    DC
    CGG
    705.0
    [m]
    DC
    CGG
    711.0
    [m]
    DC
    CGG
    717.0
    [m]
    DC
    CGG
    723.0
    [m]
    DC
    CGG
    729.0
    [m]
    DC
    CGG
    735.0
    [m]
    DC
    CGG
    741.0
    [m]
    DC
    CGG
    747.0
    [m]
    DC
    CGG
    750.0
    [m]
    DC
    CGG
    753.0
    [m]
    DC
    CGG
    756.0
    [m]
    DC
    CGG
    759.0
    [m]
    DC
    CGG
    762.0
    [m]
    DC
    CGG
    768.0
    [m]
    DC
    CGG
    774.0
    [m]
    DC
    CGG
    780.0
    [m]
    DC
    CGG
    789.0
    [m]
    DC
    CGG
    798.0
    [m]
    DC
    CGG
    807.0
    [m]
    DC
    CGG
    816.0
    [m]
    DC
    CGG
    825.0
    [m]
    DC
    CGG
    834.0
    [m]
    DC
    CGG
    843.0
    [m]
    DC
    CGG
    852.0
    [m]
    DC
    CGG
    861.0
    [m]
    DC
    CGG
    870.0
    [m]
    DC
    CGG
    879.0
    [m]
    DC
    CGG
    888.0
    [m]
    DC
    CGG
    897.0
    [m]
    DC
    CGG
    906.0
    [m]
    DC
    CGG
    915.0
    [m]
    DC
    CGG
    924.0
    [m]
    DC
    CGG
    933.0
    [m]
    DC
    CGG
    942.0
    [m]
    DC
    CGG
    951.0
    [m]
    DC
    CGG
    960.0
    [m]
    DC
    CGG
    969.0
    [m]
    DC
    CGG
    978.0
    [m]
    DC
    CGG
    987.0
    [m]
    DC
    CGG
    996.0
    [m]
    DC
    CGG
    1005.0
    [m]
    DC
    CGG
    1014.0
    [m]
    DC
    CGG
    1023.0
    [m]
    DC
    CGG
    1032.0
    [m]
    DC
    CGG
    1041.0
    [m]
    DC
    CGG
    1050.0
    [m]
    DC
    CGG
    1059.0
    [m]
    DC
    CGG
    1068.0
    [m]
    DC
    CGG
    1077.0
    [m]
    DC
    CGG
    1086.0
    [m]
    DC
    CGG
    1095.0
    [m]
    DC
    CGG
    1104.0
    [m]
    DC
    CGG
    1113.0
    [m]
    DC
    CGG
    1122.0
    [m]
    DC
    CGG
    1131.0
    [m]
    DC
    CGG
    1140.0
    [m]
    DC
    CGG
    1149.0
    [m]
    DC
    CGG
    1158.0
    [m]
    DC
    CGG
    1167.0
    [m]
    DC
    CGG
    1176.0
    [m]
    DC
    CGG
    1194.0
    [m]
    DC
    CGG
    1203.0
    [m]
    DC
    CGG
    1212.0
    [m]
    DC
    CGG
    1221.0
    [m]
    DC
    CGG
    1230.0
    [m]
    DC
    CGG
    1239.0
    [m]
    DC
    CGG
    1248.0
    [m]
    DC
    CGG
    1269.0
    [m]
    DC
    CGG
    1290.0
    [m]
    DC
    CGG
    1311.0
    [m]
    DC
    CGG
    1332.0
    [m]
    DC
    CGG
    1350.0
    [m]
    DC
    CGG
    1370.0
    [m]
    DC
    CGG
    1391.0
    [m]
    DC
    CGG
    1410.0
    [m]
    DC
    CGG
    1430.0
    [m]
    DC
    CGG
    1450.0
    [m]
    DC
    CGG
    1470.0
    [m]
    DC
    CGG
    1490.0
    [m]
    DC
    CGG
    1510.0
    [m]
    DC
    CGG
    1530.0
    [m]
    DC
    CGG
    1550.0
    [m]
    DC
    CGG
    1570.0
    [m]
    DC
    CGG
    1590.0
    [m]
    DC
    CGG
    1616.0
    [m]
    DC
    CGG
    1630.0
    [m]
    DC
    CGG
    1650.0
    [m]
    DC
    CGG
    1670.0
    [m]
    DC
    CGG
    1690.0
    [m]
    DC
    CGG
    1710.0
    [m]
    DC
    CGG
    1730.0
    [m]
    DC
    CGG
    1750.0
    [m]
    DC
    CGG
    1770.0
    [m]
    DC
    CGG
    1790.0
    [m]
    DC
    CGG
    1810.0
    [m]
    DC
    CGG
    1830.0
    [m]
    DC
    CGG
    1850.0
    [m]
    DC
    CGG
    1870.0
    [m]
    DC
    CGG
    1890.0
    [m]
    DC
    CGG
    1910.0
    [m]
    DC
    CGG
    1930.0
    [m]
    DC
    CGG
    1950.0
    [m]
    DC
    CGG
    1970.0
    [m]
    DC
    CGG
    1976.8
    [m]
    SWC
    CGG
    1990.0
    [m]
    DC
    CGG
    2010.0
    [m]
    DC
    CGG
    2030.0
    [m]
    DC
    CGG
    2050.0
    [m]
    DC
    CGG
    2070.0
    [m]
    DC
    CGG
    2090.0
    [m]
    DC
    CGG
    2110.0
    [m]
    DC
    CGG
    2130.0
    [m]
    DC
    CGG
    2150.0
    [m]
    DC
    CGG
    2170.0
    [m]
    DC
    CGG
    2190.0
    [m]
    DC
    CGG
    2210.0
    [m]
    DC
    CGG
    2230.0
    [m]
    DC
    CGG
    2250.0
    [m]
    DC
    CGG
    2270.0
    [m]
    DC
    CGG
    2286.3
    [m]
    SWC
    CGG
    2290.0
    [m]
    DC
    CGG
    2310.0
    [m]
    DC
    CGG
    2330.0
    [m]
    DC
    CGG
    2350.0
    [m]
    DC
    CGG
    2370.0
    [m]
    DC
    CGG
    2380.0
    [m]
    DC
    CGG
    2390.0
    [m]
    DC
    CGG
    2400.0
    [m]
    DC
    CGG
    2408.0
    [m]
    SWC
    CGG
    2409.0
    [m]
    DC
    CGG
    2418.0
    [m]
    DC
    CGG
    2427.0
    [m]
    DC
    CGG
    2490.0
    [m]
    DC
    CGG
    2511.0
    [m]
    DC
    CGG
    2532.0
    [m]
    DC
    CGG
    2553.0
    [m]
    DC
    CGG
    2572.0
    [m]
    SWC
    CGG
    2574.0
    [m]
    DC
    CGG
    2595.0
    [m]
    DC
    CGG
    2616.0
    [m]
    DC
    CGG
    2637.0
    [m]
    DC
    CGG
    2658.0
    [m]
    DC
    CGG
    2660.0
    [m]
    SWC
    CGG
    2679.0
    [m]
    DC
    CGG
    2700.0
    [m]
    DC
    CGG
    2715.0
    [m]
    SWC
    CGG
    2721.0
    [m]
    DC
    CGG
    2742.0
    [m]
    DC
    CGG
    2763.0
    [m]
    DC
    CGG
    2784.0
    [m]
    DC
    CGG
    2805.0
    [m]
    DC
    CGG
    2812.0
    [m]
    SWC
    CGG
    2826.0
    [m]
    DC
    CGG
    2847.0
    [m]
    DC
    CGG
    2868.0
    [m]
    DC
    CGG
    2889.0
    [m]
    DC
    CGG
    2897.0
    [m]
    SWC
    CGG
    2910.0
    [m]
    DC
    CGG
    2931.0
    [m]
    DC
    CGG
    2952.0
    [m]
    DC
    CGG
    2973.0
    [m]
    DC
    CGG
    2984.0
    [m]
    SWC
    CGG
    2994.0
    [m]
    DC
    CGG
    3015.0
    [m]
    DC
    CGG
    3036.0
    [m]
    DC
    CGG
    3057.0
    [m]
    DC
    CGG
    3078.0
    [m]
    DC
    CGG
    3081.0
    [m]
    SWC
    CGG
    3099.0
    [m]
    DC
    CGG
    3120.0
    [m]
    DC
    CGG
    3141.0
    [m]
    DC
    CGG
    3162.0
    [m]
    DC
    CGG
    3175.0
    [m]
    SWC
    CGG
    3183.0
    [m]
    DC
    CGG
    3201.0
    [m]
    DC
    CGG
    3213.0
    [m]
    DC
    CGG
    3225.0
    [m]
    DC
    CGG
    3237.0
    [m]
    DC
    CGG
    3249.0
    [m]
    DC
    CGG
    3257.0
    [m]
    SWC
    CGG
    3261.0
    [m]
    DC
    CGG
    3273.0
    [m]
    DC
    CGG
    3285.0
    [m]
    DC
    CGG
    3297.0
    [m]
    DC
    CGG
    3309.0
    [m]
    DC
    CGG
    3321.0
    [m]
    DC
    CGG
    3322.5
    [m]
    SWC
    CGG
    3333.0
    [m]
    DC
    CGG
    3345.0
    [m]
    DC
    CGG
    3357.0
    [m]
    DC
    CGG
    3369.0
    [m]
    DC
    CGG
    3373.5
    [m]
    SWC
    CGG
    3381.0
    [m]
    DC
    CGG
    3393.0
    [m]
    DC
    CGG
    3395.2
    [m]
    SWC
    CGG
    3405.0
    [m]
    DC
    CGG
    3415.0
    [m]
    SWC
    CGG
    3420.0
    [m]
    DC
    CGG
    3435.0
    [m]
    DC
    CGG
    3445.0
    [m]
    SWC
    CGG
    3450.0
    [m]
    DC
    CGG
    3459.0
    [m]
    DC
    CGG
    3462.5
    [m]
    SWC
    CGG
    3474.0
    [m]
    DC
    CGG
    3489.0
    [m]
    DC
    CGG
    3491.0
    [m]
    SWC
    CGG
    3504.0
    [m]
    DC
    CGG
    3518.0
    [m]
    SWC
    CGG
    3519.0
    [m]
    DC
    CGG
    3528.0
    [m]
    DC
    CGG

  • Lithostratigraphy

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    0
    0

  • 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
    385.9
    41
    388.2
    0.00
    SURF.COND.
    20
    594.6
    26
    601.0
    1.39
    FIT
    INTERM.
    13 3/8
    952.6
    17 1/2
    962.0
    1.50
    FIT
    LINER
    9 5/8
    1849.0
    12 1/4
    1851.0
    1.83
    LOT
    LINER
    7
    3144.3
    8 1/2
    3400.0
    1.61
    FIT
    OPEN HOLE
    3528.0
    6
    3528.0
    0.00

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    379
    1.35
    25.0
    KCl/Polymer/GEM
    500
    1.03
    1.0
    Seawater
    595
    1.14
    17.0
    KCl/Polymer/GEM
    601
    1.35
    25.0
    KCl/Polymer/GEM
    612
    1.14
    17.0
    KCl/Polymer/GEM
    1035
    1.14
    21.0
    KCl/Polymer/GEM
    1766
    1.15
    17.0
    KCl/Polymer/GEM
    1766
    1.14
    593.0
    KCl/Polymer/GEM
    1818
    1.14
    18.0
    Innovert
    1851
    1.15
    18.0
    KCl/Polymer/GEM
    1860
    1.14
    18.0
    Innovert
    2944
    1.37
    20.0
    Innovert
    3020
    1.14
    14.0
    Innovert
    3079
    1.37
    21.0
    Innovert
    3131
    1.14
    14.0
    Innovert
    3148
    1.37
    21.0
    Innovert
    3150
    1.28
    17.0
    Innovert
    3150
    1.32
    21.0
    Innovert
    3240
    1.14
    18.0
    Innovert
    3400
    1.28
    17.0
    Innovert
    3400
    1.14
    16.0
    Innovert
    3419
    1.37
    20.0
    Innovert
    3528
    1.37
    21.0
    Innovert