Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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15.07.2024 - 01:28
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7122/6-2

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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.
    7122/6-2
    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.
    BARENTS 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.
    7122/6-2
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    ST0509-inline3090 & crossline 5235
    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 ASA (old)
    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.
    1116-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.
    41
    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,
    10.08.2006
    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.
    19.09.2006
    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.
    19.09.2008
    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.
    18.12.2008
    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.
    GAS
    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 TRIASSIC
    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.
    SNADD FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    23.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    408.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3070.0
    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).
    3070.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    1.8
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    100
    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 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.
    KOBBE FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    71° 35' 13.6'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    22° 51' 21.54'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7944100.00
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    565425.04
    UTM zone
    Universal Transverse Mercator zone. Examples of legal values: 31, 32, 33, 34.
    34
    NPDID wellbore
    Norwegian Offshore Directorate's unique id for the wellbore.
    5327
  • Wellbore history

    General
    Block 7122/6 is situated in the Hammerfest Basin, ca. 45 km NNE of the Goliath Discovery, and ca. 55 km east of the Snøhvit Field. Well 7122/6-2 was drilled on the Tornerose prospect, a southwest dipping rotated fault block forming a structural closure with the north-eastern side delineated by a major NW-SE striking fault. Wildcat 7122/6-1 had been drilled by Total in 1987 and proven gass in the northwestern part of the structure. The primary objective of well 7122/6-2 was to prove hydrocarbons in sandstones of early Carnian age in the Snadd Formation, Kap Toscana Group. Sandstones in the Stø and Kobbe Formations were secondary targets.
    Operations and results
    Well 7122/6-2 was spudded with the semi-submersible installation Polar Pioneer on 9 August 2006 and drilled to TD at
    3070 m in the Middle Triassic Kobbe Formation. No shallow gas was observed. No significant technical problems were encountered in the operations. The well was drilled with seawater and hi-vis pills down to 1105 m, and with Glydril mud from 1105 m to TD.
    Well 7122/6-2 penetrated rocks of Quaternary, Cretaceous, Jurassic, and Triassic age. Gas was proven in the Top Carnian tight sandstones (Snadd Formation) at 2387 m. No gas water contact could be established. Instead, MDT pressure points indicated that the gas occurred in separate sands without pressure communication. The fluorescence observed in the well was indicative of light hydrocarbons only. No direct fluorescence was observed. Rare traces of pale white very faint immediate cut fluorescence were observed in the interval 2048 to 2052 m. Rare traces of pale white very faint delayed cut fluorescence in the cored interval at 2452 to 2456 m. In the interval 2574 - 2643 m rare traces of very faint bluish white delayed cut fluorescence was observed.
    One core was cut at 2452 - 2506 m in the Snadd Formation in the Top Carnian reservoir, as planned. MDT fluid samples were collected in the Stø and Carnian sandstones.Water samples were collected in the Stø and Snadd Formations. Gas samples were taken in Snadd Formation and in Carnian Sandstone at 2393.4 m, 2452.4 m and 2533.4 m.
    The well was permanently abandoned on 19 September 2006 as a gas 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]
    1120.00
    3009.00
  • 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
    2452.0
    2506.7
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    54.7
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES
  • Palynological slides at the Norwegian Offshore Directorate

    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1120.0
    [m]
    DC
    FUGRO
    1140.0
    [m]
    DC
    FUGRO
    1180.0
    [m]
    DC
    FUGRO
    1200.0
    [m]
    DC
    FUGRO
    1240.0
    [m]
    DC
    FUGRO
    1260.0
    [m]
    DC
    FUGRO
    1280.0
    [m]
    DC
    FUGRO
    1300.0
    [m]
    DC
    FUGRO
    1320.0
    [m]
    DC
    FUGRO
    1340.0
    [m]
    DC
    FUGRO
    1360.0
    [m]
    DC
    FUGRO
    1380.0
    [m]
    DC
    FUGRO
    1400.0
    [m]
    DC
    FUGRO
    1420.0
    [m]
    DC
    FUGRO
    1440.0
    [m]
    DC
    FUGRO
    1460.0
    [m]
    DC
    FUGRO
    1480.0
    [m]
    DC
    FUGRO
    1500.0
    [m]
    DC
    FUGRO
    1520.0
    [m]
    DC
    FUGRO
    1540.0
    [m]
    DC
    FUGRO
    1560.0
    [m]
    DC
    FUGRO
    1580.0
    [m]
    DC
    FUGRO
    1600.0
    [m]
    DC
    FUGRO
    1620.0
    [m]
    DC
    FUGRO
    1640.0
    [m]
    DC
    FUGRO
    1660.0
    [m]
    DC
    FUGRO
    1680.0
    [m]
    DC
    FUGRO
    1700.0
    [m]
    DC
    FUGRO
    1720.0
    [m]
    DC
    FUGRO
    1740.0
    [m]
    DC
    FUGRO
    1760.0
    [m]
    DC
    FUGRO
    1780.0
    [m]
    DC
    FUGRO
    1800.0
    [m]
    DC
    FUGRO
    1821.0
    [m]
    DC
    FUGRO
    1842.0
    [m]
    DC
    FUGRO
    1860.0
    [m]
    DC
    FUGRO
    1878.0
    [m]
    DC
    FUGRO
    1905.0
    [m]
    DC
    FUGRO
    1947.0
    [m]
    DC
    FUGRO
    1968.0
    [m]
    DC
    FUGRO
    1989.0
    [m]
    DC
    FUGRO
    2001.0
    [m]
    DC
    FUGRO
    2010.0
    [m]
    DC
    FUGRO
    2019.0
    [m]
    DC
    FUGRO
    2028.0
    [m]
    DC
    FUGRO
    2037.0
    [m]
    DC
    FUGRO
    2055.0
    [m]
    DC
    FUGRO
    2064.0
    [m]
    DC
    FUGRO
    2073.0
    [m]
    DC
    FUGRO
    2082.0
    [m]
    DC
    FUGRO
    2091.0
    [m]
    DC
    FUGRO
    2100.0
    [m]
    DC
    FUGRO
    2112.0
    [m]
    DC
    FUGRO
    2121.0
    [m]
    DC
    FUGRO
    2130.0
    [m]
    DC
    FUGRO
    2139.0
    [m]
    DC
    FUGRO
    2148.0
    [m]
    DC
    FUGRO
    2157.0
    [m]
    DC
    FUGRO
    2166.0
    [m]
    DC
    FUGRO
    2175.0
    [m]
    DC
    FUGRO
    2184.0
    [m]
    DC
    FUGRO
    2193.0
    [m]
    DC
    FUGRO
    2202.0
    [m]
    DC
    FUGRO
    2211.0
    [m]
    DC
    FUGRO
    2220.0
    [m]
    DC
    FUGRO
    2232.0
    [m]
    DC
    FUGRO
    2241.0
    [m]
    DC
    FUGRO
    2250.0
    [m]
    DC
    FUGRO
    2259.0
    [m]
    DC
    FUGRO
    2268.0
    [m]
    DC
    FUGRO
    2277.0
    [m]
    DC
    FUGRO
    2286.0
    [m]
    DC
    FUGRO
    2295.0
    [m]
    DC
    FUGRO
    2304.0
    [m]
    DC
    FUGRO
    2313.0
    [m]
    DC
    FUGRO
    2322.0
    [m]
    DC
    FUGRO
    2331.0
    [m]
    DC
    FUGRO
    2340.0
    [m]
    DC
    FUGRO
    2367.0
    [m]
    DC
    FUGRO
    2376.0
    [m]
    DC
    FUGRO
    2388.0
    [m]
    DC
    FUGRO
    2394.0
    [m]
    DC
    FUGRO
    2403.0
    [m]
    DC
    FUGRO
    2412.0
    [m]
    DC
    FUGRO
    2421.0
    [m]
    DC
    FUGRO
    2430.0
    [m]
    DC
    FUGRO
    2439.0
    [m]
    DC
    FUGRO
    2448.0
    [m]
    DC
    FUGRO
    2453.5
    [m]
    DC
    FUGRO
    2455.0
    [m]
    C
    ICHRON
    2458.8
    [m]
    C
    ICHRON
    2461.8
    [m]
    C
    ICHRON
    2469.8
    [m]
    C
    ICHRON
    2471.6
    [m]
    C
    ICHRON
    2485.7
    [m]
    C
    ICHRON
    2490.7
    [m]
    C
    ICHRON
    2503.0
    [m]
    C
    ICHRON
    2506.6
    [m]
    DC
    FUGRO
    2514.0
    [m]
    DC
    FUGRO
    2523.0
    [m]
    DC
    FUGRO
    2532.0
    [m]
    DC
    FUGRO
    2541.0
    [m]
    DC
    FUGRO
    2550.0
    [m]
    DC
    FUGRO
    2559.0
    [m]
    DC
    FUGRO
    2568.0
    [m]
    DC
    FUGRO
    2577.0
    [m]
    DC
    FUGRO
    2586.0
    [m]
    DC
    FUGRO
    2595.0
    [m]
    DC
    FUGRO
    2604.0
    [m]
    DC
    FUGRO
    2613.0
    [m]
    DC
    FUGRO
    2622.0
    [m]
    DC
    FUGRO
    2631.0
    [m]
    DC
    FUGRO
    2640.0
    [m]
    DC
    FUGRO
    2652.0
    [m]
    DC
    FUGRO
    2661.0
    [m]
    DC
    FUGRO
    2670.0
    [m]
    DC
    FUGRO
    2679.0
    [m]
    DC
    FUGRO
    2688.0
    [m]
    DC
    FUGRO
    2697.0
    [m]
    DC
    FUGRO
    2706.0
    [m]
    DC
    FUGRO
    2715.0
    [m]
    DC
    FUGRO
    2724.0
    [m]
    DC
    FUGRO
    2733.0
    [m]
    DC
    FUGRO
    2742.0
    [m]
    DC
    FUGRO
    2754.0
    [m]
    DC
    FUGRO
    2763.0
    [m]
    DC
    FUGRO
    2772.0
    [m]
    DC
    FUGRO
    2781.0
    [m]
    DC
    FUGRO
    2790.0
    [m]
    DC
    FUGRO
    2799.0
    [m]
    DC
    FUGRO
    2808.0
    [m]
    DC
    FUGRO
    2817.0
    [m]
    DC
    FUGRO
    2826.0
    [m]
    DC
    FUGRO
    2835.0
    [m]
    DC
    FUGRO
    2844.0
    [m]
    DC
    FUGRO
    2853.0
    [m]
    DC
    FUGRO
    2862.0
    [m]
    DC
    FUGRO
    2871.0
    [m]
    DC
    FUGRO
    2880.0
    [m]
    DC
    FUGRO
    2889.0
    [m]
    DC
    FUGRO
    2898.0
    [m]
    DC
    FUGRO
    2907.0
    [m]
    DC
    FUGRO
    2919.0
    [m]
    DC
    FUGRO
  • Lithostratigraphy

  • Composite logs

    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.32
  • Geochemical information

    Geochemical information
    Document name
    Document format
    Document size [MB]
    txt
    0.00
    txt
    0.40
    pdf
    0.38
    pdf
    2.16
  • Logs

    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    FMI MSIP PPC
    2043
    3070
    MDT GR MINI-DST
    2393
    2452
    MDT PRESS
    2050
    2759
    MDT SAMPLE
    2533
    3037
    MSCT
    2206
    3059
    MWD - ON TRAK
    482
    3070
    PEX HRLA
    2910
    3070
    PEX HRLA CMR ECS HNGS
    2016
    2998
    VSP
    882
    3060
  • 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
    478.0
    36
    482.0
    0.00
    LOT
    SURF.COND.
    13 3/8
    1088.0
    17 1/2
    1104.0
    1.50
    LOT
    INTERM.
    9 5/8
    2043.0
    12 1/4
    2044.0
    1.50
    LOT
    OPEN HOLE
    3070.0
    8 1/2
    3070.0
    0.00
    LOT
  • Drilling mud

    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    482
    1.45
    SW / BENTONITE 1
    1104
    1.25
    24.0
    GLYDRIL 74
    1615
    1.28
    21.0
    GLYDRIL 74
    2044
    1.28
    22.0
    GLYDRIL 74
    2044
    1.30
    24.0
    GLYDRIL 74
    3070
    1.28
    18.0
    GLYDRIL 74
  • Thin sections at the Norwegian Offshore Directorate

    Thin sections at the Norwegian Offshore Directorate
    Depth
    Unit
    2452.28
    [m ]
    2456.01
    [m ]
    2457.22
    [m ]
    2466.03
    [m ]
    2484.02
    [m ]
    2501.26
    [m ]
    2502.39
    [m ]
  • Pressure plots

    Pressure plots
    The pore pressure data is sourced from well logs if no other source is specified. In some wells where pore pressure logs do not exist, information from Drill stem tests and kicks have been used. The data has been reported to the NPD, and further processed and quality controlled by IHS Markit.
    Pressure plots
    Document name
    Document format
    Document size [MB]
    pdf
    0.28