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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30/11-7 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.
    30/11-7 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
    Multilateral
    Indicator telling if the parent well is multilateral, meaning it has more than one branch radiating from the main borehole. Example of legal values: YES, NO. See also Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    NO
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    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.
    30/11-7
    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.
    StatoilHydro 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.
    1239-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.
    54
    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,
    02.04.2009
    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.
    25.05.2009
    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.
    25.05.2011
    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.
    25.05.2011
    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
    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.
    GAS/CONDENSATE
    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.
    111.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4250.0
    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).
    4137.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    31.5
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    143
    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° 0' 21.24'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 22' 25.62'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6652389.10
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    465075.91
    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.
    6085

  • Wellbore history
    General
    Well 30/11-7 A is a sidetrack from well 30/11-7 on the eastern flank of the Central Viking Graben, NE of the Frigg Field in the North Sea. The main well 30/11-7 discovered gas and condensate in the Middle Jurassic Ness Formation. Due to intra Heather erosion and/or faulting, the upper part of the Brent Group, the Tarbert Formation, was missing in the main well. The objectives of the sidetrack was to verify the quality and presence of the Tarbert Formation within structural closure, and to confirm the gas/water contact that was estimated from the main well pressure data.
    Operations and results
    Appraisal well 30/11-7 A was kicked off from 30/11-7 at 2846 m in the Jorsalfare Formation, on 2 April 2009. It was drilled to 4250 m (4136.9 m TVD) in the Middle Jurassic Ness Formation using the semi-submersible installation Transocean Leader. No significant problems were encountered in the operations. The well was drilled with Versatec oil based mud from kick-off to TD.
    The Viking Group was encountered at 3831.5 m (3762 m TVD) and consisted of a 175 m thick Heather Formation sequence. The top of the reservoir was penetrated at 4007 m (3915.3 m TVD) in a position located 300 m from the main well at top reservoir level. The well proved a gas/condensate filled Tarbert Formation. The Gas-Water Contact is estimated to be at 4086 m (3986.5 m TVD), 18 m TVD above top Ness Formation, based on pressure gradients. The pressure measurements in the contact area are few due to poor reservoir quality; hence the exact contact is uncertain. The result from the pressure measurements proves no communication between the reservoir in the main well and in the sidetrack. The gas/condensate in the sidetrack Tarbert Formation compartment is somewhat richer than in the main well Ness Formation compartment. Some fluorescence was observed on the cores, but the oil based mud is likely to give some fluorescence and origin of the fluorescence is uncertain.
    Five cores were cut in the interval 4022 to 4123 m in the Tarbert Formation. Core no 1 from 4022 to 4039 m recovered only 0.9 m core, otherwise the recovery was 98 - 100%. The MDT tool was run for pressure points and fluid samples. Gas was sampled at 4009.5 m and 4047.0 m using the Quicksilver probe, and at 4077.5 m using dual packer. An attempt to sample at the GWC failed due to tight formation. Water was sampled at 4185 m in the Tarbert Formation using dual packer.
    The well was permanently abandoned on 25 May 2009 as a gas/condensate 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]
    2860.00
    4248.63

  • 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
    4022.4
    4023.3
    [m ]
    2
    4039.0
    4053.2
    [m ]
    3
    4053.2
    4068.8
    [m ]
    4
    4068.8
    4096.2
    [m ]
    5
    4096.2
    4123.6
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    85.5
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • 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
    INTERM.
    9 5/8
    3417.0
    12 1/4
    3419.0
    2.01
    LOT
    OPEN HOLE
    4250.0
    8 1/2
    4250.0
    0.00
    LOT

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    MDT
    4008
    4237
    MDT MRPA (TLC)
    4077
    4231
    MDT MRPQ
    4008
    4047
    MSIP
    3417
    4235
    MWD - ARCVRES6
    4000
    4250
    MWD - ECOS GVR6 ARCVRES6 STET
    3865
    4022
    MWD - STET TELE ARCVRES6 GVR6
    3562
    3865
    MWD - STET. ARCVRES6 GVR6 TELE
    3419
    3562
    MWD LWD - ARCVRES6
    3419
    3562
    PEX AIT
    3417
    4248
    WAVSP
    785
    3417

  • Lithostratigraphy

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    194
    1.48
    30.0
    Versatec
    660
    1.48
    30.0
    Versatec
    2720
    1.48
    26.0
    Versatec
    2982
    1.53
    40.0
    Versatec
    3078
    1.61
    40.0
    Versatec
    3343
    1.75
    40.0
    Versatec
    3343
    1.60
    29.0
    Versatec
    3419
    1.76
    42.0
    Versatec
    3450
    1.83
    39.0
    Versatec
    3562
    1.90
    44.0
    Versatec
    3735
    1.89
    43.0
    Versatec
    3865
    1.91
    47.0
    Versatec
    3881
    1.90
    45.0
    Versatec
    4022
    1.91
    47.0
    Versatec
    4039
    1.91
    49.0
    Versatec
    4096
    1.91
    48.0
    Versatec
    4123
    1.91
    50.0
    Versatec
    4250
    1.91
    53.0
    Versatec
    4250
    1.91
    53.0
    Versatec