Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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25.11.2024 - 01:30
Time of last synchronization with Norwegian Offshore Directorate's internal systems

30/11-10 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.
    30/11-10 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.
    30/11-10
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    3D survey MC3D-NVG05 inline 1698 & xline 3057
    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.
    1549-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.
    45
    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,
    28.12.2014
    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.
    13.02.2015
    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.
    13.02.2015
    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.
    13.02.2017
    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.
    13.02.2017
    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.
    TARBERT FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    23.5
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    104.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3948.0
    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).
    3696.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    44.4
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    129
    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° 14' 4.27'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 30' 37.16'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6677786.79
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    472879.26
    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.
    7602

  • Wellbore history
    General
    Well 30/11-10 A was drilled as a geological sidetrack to 30/11-10 in order to appraise the Krafla discovery made by well 30/11-8 S in 2011. Krafla is located south of and close to the Krafla North discovery made by the 30/11-10 well, on the edge of the Horda Platform towards the Viking Graben. The primary objective was to reduce uncertainty in oil-in-place in Krafla and to verify communication with Krafla North. Secondary objective was to obtain high-quality fluid samples from Krafla Tarbert Formation.
    Operations and results
    Wildcat well 30/11-10 A was kicked off from 2001 m in 30/11-10 on 28 December 2014. It was drilled with the semi-submersible installation Transocean Leader to TD at 3948 m (3696 m TVD) m in the Middle Jurassic Ness Formation. On 10 January 2015, at 3777 m in the 8 1/2" section, drilling was discontinued for 12 days due to damaged top drive and bad weather. Otherwise, no significant problem was encountered in the operations. The well was drilled with XP-07 oil based mud from kick-off to TD.
    Top Brent Group, Tarbert Formation was penetrated at 3610 m (3359.2 m TVD). Hydrocarbons were proven in the Tarbert Formation from 3654 m (3403 m TVD) with a main oil bearing sandstone between 3717 to 3731 m (3466 to 3480 m TVD). Pressure points and logs indicate an OWC around 3753 m (3502 m TVD). Shows were described in Tarbert and Ness formations.
    No cores were cut in the well. Pressures in Tarbert Formation are close to those seen in 30/11-10 Krafla North, but variable pressure measurements in Krafla North did not provide reliable gradients so communication within Tarbert between Krafla and Krafla North cannot be concluded. Pressures within the Ness Formation does not support communication between Krafla and Krafla North. MDT fluid samples were taken at 3655.5 m (oil), 3660.4 m (water), 3683.5 m (oil), 3693.5 m (oil), 3719.1 m (oil), 3764.3 m (water).
    The well was permanently abandoned on 13 February 2015 as an oil appraisal 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]
    2010.00
    3948.00

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    3547.0
    [m]
    DC
    PETROSTR
    3559.0
    [m]
    DC
    PETROS
    3571.0
    [m]
    DC
    PETROS
    3583.0
    [m]
    DC
    PETROS
    3595.0
    [m]
    DC
    PETROS
    3604.0
    [m]
    DC
    PETROS
    3607.0
    [m]
    DC
    PETROS
    3610.0
    [m]
    DC
    PETROS
    3613.0
    [m]
    DC
    PETROS
    3616.0
    [m]
    DC
    PETROS
    3619.0
    [m]
    DC
    PETROS
    3622.0
    [m]
    DC
    PETROS
    3625.0
    [m]
    DC
    PETROS
    3631.0
    [m]
    DC
    PETROS
    3640.0
    [m]
    DC
    PETROS
    3649.0
    [m]
    DC
    PETROS
    3658.0
    [m]
    DC
    PETROS
    3664.0
    [m]
    DC
    PETROS
    3676.0
    [m]
    DC
    PETROS
    3682.0
    [m]
    DC
    PETROS
    3694.0
    [m]
    DC
    PETROS
    3700.0
    [m]
    DC
    PETROS
    3709.0
    [m]
    DC
    PETROS
    3730.0
    [m]
    DC
    PETROS
    3736.0
    [m]
    DC
    PETROS
    3745.0
    [m]
    DC
    PETROS
    3751.0
    [m]
    DC
    PETROS
    3769.0
    [m]
    DC
    PETROS
    3781.0
    [m]
    DC
    PETROS
    3793.0
    [m]
    DC
    PETROS
    3805.0
    [m]
    DC
    PETROS
    3814.0
    [m]
    DC
    PETROS
    3820.0
    [m]
    DC
    PETROS
    3826.0
    [m]
    DC
    PETROS
    3832.0
    [m]
    DC
    PETROS
    3844.0
    [m]
    DC
    PETROS
    3853.0
    [m]
    DC
    PETROS
    3862.0
    [m]
    DC
    PETROS
    3868.0
    [m]
    DC
    PETROS
    3883.0
    [m]
    DC
    PETROS
    3895.0
    [m]
    DC
    PETROS
    3907.0
    [m]
    DC
    PETROS
    3919.0
    [m]
    DC
    PETROS
    3928.0
    [m]
    DC
    PETROS
    3940.0
    [m]
    DC
    PETROS
    3949.0
    [m]
    DC
    PETROS

  • Oil samples at the Norwegian Offshore Directorate
    Oil samples at the Norwegian Offshore Directorate
    Test type
    Bottle number
    Top depth
    MD [m]
    Bottom depth
    MD [m]
    Fluid type
    Test time
    Samples available
    MDT
    3693.50
    0.00
    OIL
    YES
    MDT
    3683.50
    0.00
    OIL
    YES
    MDT
    3719.00
    0.00
    OIL
    YES

  • Lithostratigraphy

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    AIT PEX HNGS
    3495
    3955
    CMR RCS GR
    3429
    3955
    MDT
    3655
    3719
    MDT
    3660
    3764
    MDT
    3719
    3719
    MDT MINIDST
    3683
    3683
    MWD - ARCVIS6 TELE
    3532
    3948
    MWD - ARCVIS8 XCEED TELE
    2007
    3532
    MWD - GWD TELE
    2001
    2001
    NGI SS
    2865
    3955
    XL ROCK
    3654
    3760

  • 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
    178.4
    36
    184.0
    0.00
    SURF.COND.
    20
    798.2
    26
    807.0
    1.35
    FIT
    PILOT HOLE
    1652.0
    12 1/4
    1652.0
    0.00
    LINER
    9 5/8
    3529.0
    12 1/4
    3532.0
    0.00
    3535.0
    3535.0
    2.15
    FIT
    OPEN HOLE
    3948.0
    8 1/2
    3948.0
    0.00

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    2654
    1.35
    20.0
    OBM-Low ECD
    3271
    1.35
    20.0
    OBM-Low ECD
    3323
    1.30
    15.0
    OBM-Low ECD
    3323
    1.46
    31.0
    OBM-Low ECD
    3331
    1.35
    19.0
    OBM-Low ECD
    3390
    1.46
    29.0
    OBM-Low ECD
    3390
    1.35
    20.0
    OBM-Low ECD
    3478
    1.46
    29.0
    OBM-Low ECD
    3489
    1.35
    21.0
    OBM-Low ECD
    3532
    1.39
    23.0
    OBM-Low ECD
    3532
    1.39
    23.0
    OBM-Low ECD
    3532
    1.35
    19.0
    OBM-Low ECD
    3689
    1.37
    21.0
    OBM-Low ECD
    3770
    1.40
    22.0
    OBM-Low ECD
    3881
    1.45
    31.0
    OBM-Low ECD
    3949
    1.46
    25.0
    OBM-Low ECD