Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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22.12.2024 - 01:25
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30/6-31 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.
    30/6-31 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 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
    Well name
    Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    30/6-31
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    CGG17M01 inline 5911
    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.
    1804-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.
    22
    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,
    04.04.2020
    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.
    25.04.2020
    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.
    25.04.2020
    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.
    25.04.2022
    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.
    08.08.2022
    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.
    107.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2852.0
    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).
    2830.0
    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.
    MIDDLE 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.
    NESS FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    60° 33' 12.9'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 52' 12.27'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6713230.30
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    492874.14
    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.
    8979

  • Wellbore history
    General
    Well 30/6-31 S was drilled to test the Helleneset prospect between the Oseberg and Brage fields on the Oseberg Fault block in the North Sea. The primary objective was to test the hydrocarbon potential in Callovian Intra-Heather Formation sandstones.
    Operations and results
    A shallow gas pilot hole 30/6-U-28 was spudded 18 m south of the main well location on 9 March 2020. Due to weather and other problems, this well was aborted after drilling down to 511 m. A second pilot hole (drilled with 8 ½” BHA) was then drilled from 30/6-31 S well location down to 1120 m. Based on the log interpretation, flow checks, sonar and ROV observations, there were no shallow gas observed from these pilot holes.
    Wildcat well 30/6-31 S was spudded with the semi-submersible installation West Hercules on 4 April 2020 and drilled to TD at 2852 m (2830.4 m TVD) in the Middle Jurassic Ness Formation. Operations proceeded without significant problems. The well was drilled with seawater and hi-vis pills down to 1120 m, with Versatec oil-based mud from 1120 m to 2649 m, and with Exploradrill oil-based mud from 2649 m to TD.
    High formation gas levels were  observed in limestones within Shetland Group in the 12 ¼” section. The limestones are correlated with Shetland limestone in Oseberg Main Field. A gas chimney is observed in the seismic, showing potential leak to overburden and which may charge the Shetland limestone at the well location.
    The targeted Jurassic Callovian syn-rift reservoir was poorly developed and appear as thin cemented sands without any indication of hydrocarbons from the logs, gas, or cuttings. A thin Tarbert Formation was drilled, and no hydrocarbon indications were encountered. The pressure measurement acquired in Heather-Callovian, Tarbert and Ness sand concluded a depleted pressure (100 bar depletion in the Ness Formation.).
    No cores were cut. No fluid sample was taken.
    The well was permanently abandoned on 25 April 2020 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]
    1130.00
    2850.00

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1130.0
    [m]
    DC
    APT
    1170.0
    [m]
    DC
    APT
    1210.0
    [m]
    DC
    APT
    1250.0
    [m]
    DC
    APT
    1290.0
    [m]
    DC
    APT
    1330.0
    [m]
    DC
    APT
    1370.0
    [m]
    DC
    APT
    1410.0
    [m]
    DC
    APT
    1450.0
    [m]
    DC
    APT
    1490.0
    [m]
    DC
    APT
    1530.0
    [m]
    DC
    APT
    1570.0
    [m]
    DC
    APT
    1610.0
    [m]
    DC
    APT
    1650.0
    [m]
    DC
    APT
    1680.0
    [m]
    DC
    APT
    2100.0
    [m]
    DC
    APT
    2120.0
    [m]
    DC
    APT
    2140.0
    [m]
    DC
    APT
    2160.0
    [m]
    DC
    APT
    2180.0
    [m]
    DC
    APT
    2200.0
    [m]
    DC
    APT
    2260.0
    [m]
    DC
    APT
    2280.0
    [m]
    DC
    APT
    2300.0
    [m]
    DC
    APT
    2320.0
    [m]
    DC
    APT
    2370.0
    [m]
    DC
    APT
    2400.0
    [m]
    DC
    APT
    2430.0
    [m]
    DC
    APT
    2510.0
    [m]
    DC
    APT
    2515.0
    [m]
    DC
    APT
    2520.0
    [m]
    DC
    APT
    2525.0
    [m]
    DC
    APT
    2540.0
    [m]
    DC
    APT
    2545.0
    [m]
    DC
    APT
    2550.0
    [m]
    DC
    APT
    2555.0
    [m]
    DC
    APT
    2560.0
    [m]
    DC
    APT
    2565.0
    [m]
    DC
    APT
    2570.0
    [m]
    DC
    APT
    2575.0
    [m]
    DC
    APT
    2580.0
    [m]
    DC
    APT
    2585.0
    [m]
    DC
    APT
    2590.0
    [m]
    DC
    APT
    2595.0
    [m]
    DC
    APT
    2600.0
    [m]
    DC
    APT
    2605.0
    [m]
    DC
    APT
    2610.0
    [m]
    DC
    APT
    2620.0
    [m]
    DC
    APT
    2625.0
    [m]
    DC
    APT
    2630.0
    [m]
    DC
    APT
    2635.0
    [m]
    DC
    APT
    2640.0
    [m]
    DC
    APT
    2645.0
    [m]
    DC
    APT
    2652.0
    [m]
    DC
    APT
    2664.0
    [m]
    DC
    APT
    2670.0
    [m]
    DC
    APT
    2676.0
    [m]
    DC
    APT
    2682.0
    [m]
    DC
    APT
    2688.0
    [m]
    DC
    APT
    2694.0
    [m]
    DC
    APT
    2700.0
    [m]
    DC
    APT
    2706.0
    [m]
    DC
    APT
    2712.0
    [m]
    DC
    APT
    2718.0
    [m]
    DC
    APT
    2724.0
    [m]
    DC
    APT
    2730.0
    [m]
    DC
    APT
    2736.0
    [m]
    DC
    APT
    2742.0
    [m]
    DC
    APT
    2748.0
    [m]
    DC
    APT
    2754.0
    [m]
    DC
    APT
    2760.0
    [m]
    DC
    APT
    2766.0
    [m]
    DC
    APT
    2772.0
    [m]
    DC
    APT
    2784.0
    [m]
    DC
    APT
    2790.0
    [m]
    DC
    APT
    2796.0
    [m]
    DC
    APT
    2802.0
    [m]
    DC
    APT
    2808.0
    [m]
    DC
    APT
    2814.0
    [m]
    DC
    APT
    2820.0
    [m]
    DC
    APT
    2826.0
    [m]
    DC
    APT
    2832.0
    [m]
    DC
    APT
    2838.0
    [m]
    DC
    APT
    2844.0
    [m]
    DC
    APT
    2850.0
    [m]
    DC
    APT

  • Lithostratigraphy

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    MWD - AV TS
    189
    1120
    MWD - AV TS
    2649
    2852
    MWD - ES SS TS
    187
    2649
    XPT HNGS AIT PEX
    2649
    2852

  • 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
    187.0
    42
    189.0
    0.00
    SURF.COND.
    13 3/8
    1113.0
    17 1/2
    1120.0
    1.67
    LOT
    PILOT HOLE
    1120.0
    8 1/2
    1120.0
    0.00
    LINER
    9 5/8
    2649.0
    12 1/4
    2649.0
    1.74
    LOT
    OPEN HOLE
    2852.0
    8 1/2
    2852.0
    0.00