Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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15.07.2024 - 01:28
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30/8-5

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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.
    30/8-5
    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.
    JUNKED
    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.
    30/8-5
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    CGG NVT Inline 5142. Xline 21880
    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.
    Statoil Petroleum 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.
    1678-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.
    80
    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,
    02.12.2017
    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.
    19.02.2018
    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.
    19.02.2018
    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.
    19.02.2020
    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.
    19.02.2020
    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.
    NOT APPLICABLE
    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.
    30.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    92.2
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3563.0
    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).
    3561.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    3.2
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    136
    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.
    SHETLAND GP
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    60° 28' 15.43'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 36' 15.58'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6704085.14
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    478243.75
    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.
    8315
  • Wellbore history

    General
    Well 30/8-5 was drilled on the Tune Field on the Mokkukalven Fault Complex west of the Oseberg fault block in the North Sea. The primary objective was to collect data for the development of the Tune field, Statfjord reservoir.
    Operations and results
    A 9 7/8” shallow gas pilot hole was drilled at the well location to a total depth of 500 m. No indications of shallow gas were observed.
    Appraisal well 30/8-5 was spudded with the semi-submersible installation Deepsea Atlantic on 2 December 2017.
    It was drilled to 3637 m in a sand in the Shetland Group where a fluid influx was recorded. The blow-out preventer (BOP) was closed and the well was shut in. High pressure was measured at surface. The ensuing well control situation was successfully resolved. Based on formation stress and strength at the 14” shoe the well was plugged and cemented back to the shoe. A technical side-track 30/8-5 T2 was kicked off from 30/8-5 at 3007 m. The side-track was drilled approximately 20 m north of 30/8-5. The logs from the two wellbores correlate very well but show some differences towards TD. After a drill break at 3563 m, 7 m fluid influx was again recorded, 72 m TVD above the sand with high pressure and kick in 30/8-5. It was decided to terminate the well at 3563 m. The well was drilled with seawater and hi-vis pills down to 1153 m, with Innovert NS oil-based mud down to 3156 m and with Bara ECD oil-based mud  from 3156 m to final TD.
    The well objectives were not achieved. No oil shows were observed cuttings in either wellbore. During the shut-in after the kick, the MWD memory data showed that the temperature stabilized at a 136 °C.
    No core was cut. No fluid sample was taken. Wire line logging was performed in the side-track
    The well was permanently abandoned on 19 February 2018 as a junk 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]
    3300.00
    3636.00
  • Palynological slides at the Norwegian Offshore Directorate

    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    2300.0
    [m]
    DC
    PETROSTR
    2340.0
    [m]
    DC
    PETROS
    2380.0
    [m]
    DC
    PETROS
    2420.0
    [m]
    DC
    PETROS
    2460.0
    [m]
    DC
    PETROS
    2500.0
    [m]
    DC
    PETROS
    2540.0
    [m]
    DC
    PETROS
    2580.0
    [m]
    DC
    PETROS
    2620.0
    [m]
    DC
    PETROS
    2660.0
    [m]
    DC
    PETROS
    2700.0
    [m]
    DC
    PETROS
    2740.0
    [m]
    DC
    PETROS
    2780.0
    [m]
    DC
    PETROS
    2820.0
    [m]
    DC
    PETROS
    2860.0
    [m]
    DC
    PETROS
    2900.0
    [m]
    DC
    PETROS
    2940.0
    [m]
    DC
    PETROS
    2980.0
    [m]
    DC
    PETROS
    3020.0
    [m]
    DC
    PETROS
    3060.0
    [m]
    DC
    PETROS
    3100.0
    [m]
    DC
    PETROS
    3140.0
    [m]
    DC
    PETROS
    3180.0
    [m]
    DC
    PETROS
    3200.0
    [m]
    DC
    PETROS
    3220.0
    [m]
    DC
    PETROS
    3260.0
    [m]
    DC
    PETROS
    3300.0
    [m]
    DC
    PETROS
    3318.0
    [m]
    DC
    PETROS
    3336.0
    [m]
    DC
    PETROS
    3354.0
    [m]
    DC
    PETROS
    3372.0
    [m]
    DC
    PETROS
    3384.0
    [m]
    DC
    PETROS
    3396.0
    [m]
    DC
    PETROS
    3408.0
    [m]
    DC
    PETROS
    3420.0
    [m]
    DC
    PETROS
    3426.0
    [m]
    DC
    PETROS
    3432.0
    [m]
    DC
    PETROS
    3444.0
    [m]
    DC
    PETROS
    3450.0
    [m]
    DC
    PETROS
    3462.0
    [m]
    DC
    PETROS
    3474.0
    [m]
    DC
    PETROS
    3486.0
    [m]
    DC
    PETROS
    3498.0
    [m]
    DC
    PETROS
    3510.0
    [m]
    DC
    PETROS
    3522.0
    [m]
    DC
    PETROS
    3534.0
    [m]
    DC
    PETROS
    3546.0
    [m]
    DC
    PETROS
    3558.0
    [m]
    DC
    PETROS
    3564.0
    [m]
    DC
    PETROS
    3570.0
    [m]
    DC
    PETROS
    3576.0
    [m]
    DC
    PETROS
    3582.0
    [m]
    DC
    PETROS
    3588.0
    [m]
    DC
    PETROS
    3594.0
    [m]
    DC
    PETROS
    3600.0
    [m]
    DC
    PETROS
    3606.0
    [m]
    DC
    PETROS
    3609.0
    [m]
    DC
    PETROS
    3612.0
    [m]
    DC
    PETROS
    3618.0
    [m]
    DC
    PETROS
    3624.0
    [m]
    DC
    PETROS
    3630.0
    [m]
    DC
    PETROS
    3636.0
    [m]
    DC
    PETROS
    9999.0
    [m]
    DC
    PETROS
  • Lithostratigraphy

    Lithostratigraphy
    Top depth [mMD RKB]
    Lithostrat. unit
    122
    635
    985
    2092
    2092
    2170
    2254
    2343
    2435
  • Logs

    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    MWD LWD - AT OT GR RES
    3156
    3637
    MWD LWD - GR RES
    122
    500
    MWD LWD - OT GR RES
    212
    3156
    T2 - MWD LWD - OT GR RES
    3016
    3566
    T2 - AIT MSIP PEX ECS NGI
    3000
    3563
    T2 - DCBL IBC GR
    3000
    3555
    T2 - VSP GR
    1619
    3555
  • 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
    209.5
    42
    212.0
    0.00
    SURF.COND.
    20
    1145.7
    26
    1150.0
    1.55
    FIT
    3001.0
    0.0
    1.82
    FIT
    14
    3007.0
    17 1/2
    0.0
    0.00
    LINER
    9 7/8
    3560.0
    12 1/4
    3563.0
    1.88
    FIT
    3560.0
    0.0
    1.91
    LOT
    3566.0
    8 1/2
    3566.0
    0.00
  • Drilling mud

    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    603
    1.00
    15.0
    Spud Mud
    607
    1.41
    30.0
    Innovert
    607
    1.60
    20.0
    KCl/Polymer
    607
    1.00
    13.0
    Spud Mud
    1150
    1.25
    11.0
    BARADRIL-N
    1150
    1.41
    30.0
    Innovert
    1150
    1.60
    20.0
    KCl/Polymer
    1150
    1.31
    24.0
    Innovert
    1437
    1.37
    25.0
    Innovert
    1741
    1.45
    32.0
    Innovert
    2050
    1.52
    38.0
    Enviromul
    2520
    1.45
    33.0
    Innovert
    3005
    1.70
    34.0
    BaraECD
    3051
    1.45
    33.0
    Innovert
    3070
    1.70
    34.0
    BaraECD
    3119
    1.45
    32.0
    Innovert
    3139
    1.70
    34.0
    BaraECD
    3156
    1.45
    37.0
    Innovert
    3156
    1.66
    32.0
    BaraECD
    3158
    1.70
    40.0
    BaraECD
    3158
    1.89
    45.0
    BaraECD
    3230
    1.80
    40.0
    BaraECD
    3274
    1.89
    44.0
    BaraECD
    3274
    1.42
    46.0
    BaraECD
    3276
    1.52
    39.0
    Enviromul
    3293
    1.70
    35.0
    BaraECD
    3400
    1.90
    43.0
    BaraECD
    3408
    1.71
    32.0
    BaraECD
    3563
    1.70
    33.0
    BaraECD
    3563
    1.80
    42.0
    BaraECD
    3588
    1.70
    35.0
    BaraECD
    3636
    1.89
    45.0
    BaraECD