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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7/11-11 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.
    7/11-11 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).
    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.
    7/11-11
    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.
    Talisman Energy Norge 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.
    1133-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.
    74
    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,
    29.03.2007
    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.
    10.06.2007
    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.
    10.06.2009
    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.
    10.06.2009
    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.
    OIL SHOWS
    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.
    LATE 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.
    ULA FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    43.4
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    80.4
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4679.0
    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).
    4444.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    24.3
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    168
    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.
    TRIASSIC
    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.
    SMITH BANK FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    57° 7' 34.87'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 28' 58.68'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6331711.79
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    468696.47
    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.
    5474

  • Wellbore history
    General
    Appraisal well 7/11-11 S was drilled on the Mime Field, which is situated on the Cod Terrace in the North Sea. A previous well on Mime, 7/11-10 S produced 484000 Sm3 oil equivalents between 1990 and 1993 before being abandoned due to asphaltene precipitation. In the neighbour Mime well 7 /11-5 an oil contact was found at 4176 m TVD MSL, but this was thought to be a down-to contact set by lithology and not a true OWC. The primary objective of 7/11-11 S was to prove a deeper contact within the Ula Formation reservoir zone than the contact found in 7/11-5. The appraisal was drilled on the Mime Main proven segment and, depending on the results, two sidetrack appraisals into either Mime Main or Mime West was planned.
    Operations and results
    Well 7/11-11 S was spudded with the jack-up installation Mærsk Giant on 29 March 2007 and drilled to TD at 4679 m (4444 m TVD RKB) in the Triassic Smith Bank Formation. The well path was vertical down to ca 1350 m. Angle was built to ca 24 deg at ca 1900 m and was kept within 13 - 25 deg from there to TD. It was drilled with Seawater and bentonite sweeps down to 800 m, with KCL/Polymer mud from 800 m to 1323 m, and with Carbosea invert emulsion oil based mud from 1323 m to TD.
    Top Ula Formation was encountered at 4470 m (4200 TVD MSL), 15 m shallow to prognosis. It was however 67 m thicker than expected, but the effective reservoir zone within Ula was encountered as deep as 4256 m TVD MSL due to a thicker non-reservoir top Ula sequence than expected. Station log measurements were undertaken with the CMR tool at 6 depths in the Ula Formation and interpreted via Magnetic Resonance Fluid Characterisation (MRF). The results indicated 2 hydrocarbon phases, a heavy viscous oil and a light oil (probably OBM filtrate). These results were in direct contrast to the core, produced fluids and other log evaluation. Despite efforts to resolve this enigma the CMR MRF results remain in contradiction to the other data. The reservoir was concluded to be water bearing with only some poor shows in the top ca 15 m. The rest of the well had no shows other than high gas readings in the Mandal Formation. A total of 26 pressure measurements were attempted in the Ula Sandstone (24) and Smith Bank (2) between 4501m and 4632 m using a large diameter probe and a dual packer. No stable pressures could be obtained. The maximum temperature recorded (non-corrected) was 167.9 deg C, measured at 4622 m during the final MDT run. The low permeability in the reservoir made further development of the well unviable and it was decided to plug back and abandon without testing or further sidetracks.
    Two cores were cut at 4479 to 4587 m in the Ula Formation. Core #1 at 4479 - 4533 m cut 54 m, but recovered 55.76 m due to re-packing of core. The core catcher backed off resulting in the core slipping out of the inner barrel. Thus, the core had to be retrieved from the outer barrel and inserted manually into the inner barrel. An MDT water sample was obtained from 4541 m.
    The well was permanently abandoned on 10 June 2007 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]
    220.00
    4679.00

  • 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
    4479.0
    4533.5
    [m ]
    2
    4533.5
    4588.3
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    109.3
    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
    CONDUCTOR
    30
    201.0
    36
    214.0
    0.00
    LOT
    SURF.COND.
    13 3/8
    1312.0
    17 1/2
    1322.0
    1.70
    LOT
    INTERM.
    9 5/8
    4285.0
    12 1/4
    4296.0
    1.90
    LOT
    OPEN HOLE
    4679.0
    8 1/2
    4679.0
    0.00
    LOT

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    AIT DSI EMS
    4285
    4679
    HNGS LDS APS CMR
    4285
    4679
    MDT CMR GR TLC
    4285
    4679
    MDT GR TLC
    4502
    4632
    MWD - DIR
    123
    214
    MWD - GR RES DIR PWD
    214
    4679
    VSP
    123
    4544

  • Lithostratigraphy

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    123
    1.04
    120.0
    WATER BASED
    210
    1.04
    120.0
    WATER BASED
    915
    1.03
    WATER BASED
    938
    1.18
    120.0
    WATER BASED
    1013
    1.62
    OIL BASED
    1323
    1.24
    56.0
    WATER BASED
    1722
    1.60
    WATER BASED
    1937
    1.62
    OIL BASED
    3326
    1.62
    OIL BASED
    3333
    1.62
    OIL BASED
    3402
    1.62
    OIL BASED
    3474
    1.62
    OIL BASED
    3493
    1.62
    OIL BASED
    4077
    1.62
    OIL BASED
    4181
    1.62
    OIL BASED
    4185
    1.62
    OIL BASED
    4296
    1.62
    OIL BASED
    4301
    1.62
    OIL BASED
    4679
    1.62
    OIL BASED