Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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19.06.2024 - 01:33
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6407/6-6

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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.
    6407/6-6
    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).
    WILDCAT
    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.
    NORWEGIAN 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.
    6407/6-6
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    ST04M8 inline 2455 & crossline 5495
    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 ASA
    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.
    1157-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.
    35
    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,
    02.01.2008
    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.
    05.02.2008
    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.
    05.02.2010
    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.
    05.02.2010
    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.
    YES
    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.
    FANGST GP
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    22.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    226.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2508.0
    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).
    2507.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    3.17
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    92
    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.
    EARLY 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.
    TILJE FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    64° 35' 28.82'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    7° 44' 32.03'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7163686.59
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    439783.19
    UTM zone
    Universal Transverse Mercator zone. Examples of legal values: 31, 32, 33, 34.
    32
    NPDID wellbore
    Norwegian Offshore Directorate's unique id for the wellbore.
    5636
  • Wellbore history

    General
    Well 6407/6-6 was drilled on the Gamma prospect on the eastern limits of the Halten Terrace, ca 5 km south-west of the Mikkel field. The well 6407/6-6 was the first to be drilled in production license 312. The primary objective of the well was to prove hydrocarbons in the Middle Jurassic Garn and Ile Formations in the Fangst Group and to test all prospective formations down to Åre Formation. The secondary target was to understand the origin of a seismic flat event in the Ile Formation. Shallow gas has occurred in neighbouring wells, and a shallow gas warning was given pre-drill at 380 - 420 m
    Operations and results
    Wildcat well 6407/6-6 was spudded with the semi-submersible installation Ocean Vanguard on 2 January 2008 and drilled to TD at 2508 m in the Early Jurassic Tilje Formation. A 9 7/8" pilot hole was drilled first, as a precaution against shallow gas. No shallow gas was observed. The rig was then skidded 13 m from the pilot hole for spudding of the main hole. No significant problems were encountered in the operations. The well was drilled with seawater and hi-vis pills down to 1060 m and with "Aquadrill" KCl/polymer/glycol mud from 1060 m to TD.
    The well penetrated rocks of Quaternary, Tertiary, Cretaceous, and Jurassic age. The well penetrated the Garn reservoir section at 2110 m, 3 m deeper than prognosed. A hydrocarbon discovery was proven in both the Garn and Ile Formations. In Garn, there was a hydrocarbon contact (gas down to) at 2119 m, and in Ile a true gas-water contact was noted at 2233 m. Water was detected in the Ror and Tilje formations. Results from the MDT show the Garn formation to have a permeability of around 4138 mD with a porosity of 26%. The Ile formation shows a permeability of 713 mD with a porosity of 26 %. The Tilje Formation was penetrated at 2421.5 m, 20.5 m shallower than prognosed. No shows other than a weak petroleum odour and a weak milky white to bluish white fluorescence residue on the cores from the reservoirs were reported from the well.
    Two conventional cores were cut; at 2115 - 2142 m in the Garn Formation and at 2204 - 2231 m in the Ile Formation. MDT fluid sampling and pressure points were taken in the Garn and Ile Formations. Fluid samples were taken at the following depths: 2117.1 m (gas), 2122.6 m (water), 2227.9 m (gas), and 2245.4 m (water). The samples were of good quality. Further pressure points were taken in the Ror and Tilje Formations. The pressure data showed several different pressure compartments in the Jurassic, with the Garn and Ile reservoirs in different compartments.
    The well was permanently abandoned on 5 February 2008 as a gas discovery.
    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]
    1063.00
    2507.37
  • 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
    2115.0
    2141.3
    [m ]
    2
    2204.0
    2229.8
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    52.1
    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
    2117.5
    [m]
    C
    FUGRO
    2118.7
    [m]
    C
    FUGRO
    2121.0
    [m]
    C
    FUGRO
    2121.1
    [m]
    C
    FUGRO
    2124.8
    [m]
    C
    FUGRO
    2128.2
    [m]
    C
    FUGRO
    2132.6
    [m]
    C
    FUGRO
    2133.1
    [m]
    C
    FUGRO
    2137.1
    [m]
    C
    FUGRO
    2205.0
    [m]
    C
    FUGRO
    2207.1
    [m]
    C
    FUGRO
    2211.1
    [m]
    C
    FUGRO
    2212.9
    [m]
    C
    FUGRO
    2215.5
    [m]
    C
    FUGRO
    2216.8
    [m]
    C
    FUGRO
    2218.5
    [m]
    C
    FUGRO
    2219.3
    [m]
    C
    FUGRO
    2222.9
    [m]
    C
    FUGRO
    2225.8
    [m]
    C
    FUGRO
    2227.9
    [m]
    C
    FUGRO
    2228.4
    [m]
    C
    FUGRO
  • Lithostratigraphy

  • Logs

    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    MDT GR ACTS ECRD
    2110
    2488
    MWD LWD - P.PULSE ARCVRES9 CDR6
    1055
    2508
    MWD LWD - POWERPULSE ARCVRES9
    226
    1060
    PEX MSIP HRLA ACTS ECRD
    2000
    2504
    VSP
    226
    2058
  • 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
    296.0
    36
    298.0
    0.00
    LOT
    PILOT HOLE
    547.0
    9 7/8
    547.0
    0.00
    LOT
    SURF.COND.
    13 3/8
    1054.0
    17 1/2
    1060.0
    1.66
    LOT
    SURF.COND.
    9 5/8
    2056.0
    12 1/4
    2057.0
    1.68
    LOT
    OPEN HOLE
    2508.0
    8 1/2
    2508.0
    0.00
    LOT
  • Drilling mud

    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    360
    1.03
    SPUD MUD
    547
    1.03
    SPUD MUD
    944
    1.03
    SPUD MUD
    1060
    1.35
    SPUD MUD
    1136
    1.35
    15.0
    AQUADRILL
    1733
    1.50
    21.0
    AQUADRILL
    1740
    1.50
    21.0
    AQUADRILL
    2057
    1.50
    22.0
    AQUADRILL
    2115
    1.25
    10.0
    AQUADRILL
    2143
    1.25
    16.0
    AQUADRILL
    2204
    1.25
    12.0
    AQUADRILL
    2231
    1.25
    12.0
    AQUADRILL
  • Thin sections at the Norwegian Offshore Directorate

    Thin sections at the Norwegian Offshore Directorate
    Depth
    Unit
    2123.65
    [m ]
    2128.25
    [m ]
    2135.50
    [m ]
    2218.80
    [m ]
    2229.10
    [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