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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6406/3-6

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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.
    6406/3-6
    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).
    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.
    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.
    6406/3-6
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    inline 484 & x-line 927: ST9503R99
    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.
    1040-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.
    56
    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,
    21.09.2002
    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.
    15.11.2002
    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.
    15.11.2004
    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.
    01.12.2004
    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/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.
    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.
    GARN FM
    2nd level with HC, age
    Age of lithostratigraphic unit, 2nd level, where hydrocarbons were encountered. Examples of legal values: CRETACEOUS, EARLY CRETACEOUS, LATE JURASSIC, EOCENE.
    MIDDLE JURASSIC
    2nd level with HC, formation
    Name of lithostartigraphic unit, 2nd 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.
    ILE FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    24.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    273.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4175.0
    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).
    4174.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    3.7
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    151
    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° 47' 43.56'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    6° 57' 55.17'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7187388.89
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    403326.40
    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.
    4589

  • Wellbore history
    General
    Well 6406/3-6 is located on the Halten Terrace on the western part of the Tyrihans Sør structure. The overall goal for the well was to appraise the Tyrihans Sør Discovery. The main objectives were to sample formation fluid from Tyrihans Sør in order to determine the hydrocarbon phase and to identify any possible erosion in the western part of the Discovery.
    Operations
    Appraisal well 6406/3-6 was spudded with the semi-submersible installation Stena Don on 21 October 2001. The rig drilled to a TD of 4175 m in the Jurassic Tilje Formation. The well was drilled in a water depth of 273 m, with RKB at 24 m. The well was drilled with seawater and hi-vis sweeps down to 1780 m and with Versavert oil based mud through the 12 1/4" and 8 1/2" sections from1780 m to 3654.5 m, 4.5 m into the Garn Formation. The subsequent 6" section to TD was drilled with KCl / glycol / low sulphate water-based mud (Glydril).
    The well penetrated mainly mudstones above the Jurasssic Fangst Group with siltstone intervals in the Nise and Kvitnos Formations. No shows were reported above the Fangst Group. A thick Garn Formation was found, with no trace of erosion. Hydrocarbons were found in the Garn Formation with oil-water contact at 3683 m TVD MSL, and in the upper part of the Ile Formation with oil-water contact at 3825 m TVD MSL. Good shows were recorded in the Garn and Ile Formations down to 3840 m. Due to problems with real-time data mainly memory data were available from MWD in the 8-1/2" section. Both LWD real time runs failed in the 6" section. However, wire line logging covered most of the 6" section. Recovery of sidewall cores was excellent. VSP with P+S mode sonic was gathered in the Garn Formation, and several runs were performed with MDT, collecting samples from Garn, Ile and Tilje (water) Formations. A number of pressure data points gave good correlation for gas and fluid contacts. No conventional cores were cut. The well was completed on 15 November 2002, permanently plugged and abandoned as an oil and gas appraisal.
    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]
    1790.00
    4175.00

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    3562.0
    [m]
    DC
    STATOI
    3565.0
    [m]
    DC
    STATOI
    3568.0
    [m]
    DC
    STATOI
    3571.0
    [m]
    DC
    STATOI
    3574.0
    [m]
    DC
    STATOI
    3577.0
    [m]
    DC
    STATOI
    3580.0
    [m]
    DC
    STATOI
    3583.0
    [m]
    DC
    STATOI
    3586.0
    [m]
    DC
    STATOI
    3589.0
    [m]
    DC
    STATOI
    3592.0
    [m]
    DC
    STATOI
    3595.0
    [m]
    DC
    STATOI
    3598.0
    [m]
    DC
    STATOI
    3601.0
    [m]
    DC
    STATOI
    3604.0
    [m]
    DC
    STATOI
    3610.0
    [m]
    DC
    STATOI
    3613.0
    [m]
    DC
    STATOI
    3616.0
    [m]
    DC
    STATOI
    3619.0
    [m]
    DC
    STATOI
    3622.0
    [m]
    DC
    STATOI
    3625.0
    [m]
    DC
    STATOI
    3628.0
    [m]
    DC
    STATOI
    3631.0
    [m]
    DC
    STATOI
    3634.0
    [m]
    DC
    STATOI
    3637.0
    [m]
    DC
    STATOI
    3640.0
    [m]
    DC
    STATOI
    3643.0
    [m]
    DC
    STATOI
    3646.0
    [m]
    DC
    STATOI
    3649.0
    [m]
    DC
    STATOI
    3652.0
    [m]
    DC
    STATOI
    3658.0
    [m]
    DC
    STATOI
    3661.0
    [m]
    DC
    STATOI
    3664.0
    [m]
    DC
    STATOI
    3667.0
    [m]
    DC
    STATOI
    3670.0
    [m]
    DC
    STATOI
    3676.0
    [m]
    DC
    STATOI
    3679.0
    [m]
    DC
    STATOI
    3682.0
    [m]
    DC
    STATOI
    3685.0
    [m]
    DC
    STATOI
    3688.0
    [m]
    DC
    STATOI
    3697.0
    [m]
    DC
    STATOI
    3700.0
    [m]
    DC
    STATOI
    3703.0
    [m]
    DC
    STATOI
    3706.0
    [m]
    DC
    STATOI
    3709.0
    [m]
    DC
    STATOI
    3715.0
    [m]
    DC
    STATOI
    3718.0
    [m]
    DC
    STATOI
    3721.0
    [m]
    DC
    STATOI
    3724.0
    [m]
    DC
    STATOI
    3727.0
    [m]
    DC
    STATOI
    3730.0
    [m]
    DC
    STATOI
    3733.0
    [m]
    DC
    STATOI
    3736.0
    [m]
    DC
    STATOI
    3739.0
    [m]
    DC
    STATOI
    3742.0
    [m]
    DC
    STATOI
    3745.0
    [m]
    DC
    STATOI
    3748.0
    [m]
    DC
    STATOI
    3751.0
    [m]
    DC
    STATOI
    3754.0
    [m]
    DC
    STATOI
    3757.0
    [m]
    DC
    STATOI
    3760.0
    [m]
    DC
    STATOI
    3763.0
    [m]
    DC
    STATOI
    3766.0
    [m]
    DC
    STATOI
    3769.0
    [m]
    DC
    STATOI
    3772.0
    [m]
    DC
    STATOI
    3775.0
    [m]
    DC
    STATOI
    3781.0
    [m]
    DC
    STATOI
    3784.0
    [m]
    DC
    STATOI
    3787.0
    [m]
    DC
    STATOI
    3790.0
    [m]
    DC
    STATOI
    3796.0
    [m]
    DC
    STATOI
    3802.0
    [m]
    DC
    STATOI
    3808.0
    [m]
    DC
    STATOI
    3814.0
    [m]
    DC
    STATOI
    3820.0
    [m]
    DC
    STATOI
    3826.0
    [m]
    DC
    STATOI
    3832.0
    [m]
    DC
    STATOI
    3838.0
    [m]
    DC
    STATOI
    3844.0
    [m]
    DC
    STATOI
    3850.0
    [m]
    DC
    STATOI
    3856.0
    [m]
    DC
    STATOI
    3862.0
    [m]
    DC
    STATOI
    3867.0
    [m]
    DC
    STATOI
    3873.0
    [m]
    DC
    STATOI
    3876.0
    [m]
    DC
    STATOI
    3882.0
    [m]
    DC
    STATOI
    3888.0
    [m]
    DC
    STATOI
    3891.0
    [m]
    DC
    STATOI
    3897.0
    [m]
    DC
    STATOI
    3903.0
    [m]
    DC
    STATOI
    3909.0
    [m]
    DC
    STATOI
    3915.0
    [m]
    DC
    STATOI
    3921.0
    [m]
    DC
    STATOI
    3927.0
    [m]
    DC
    STATOI
    3933.0
    [m]
    DC
    STATOI
    3940.0
    [m]
    DC
    STATOI
    3945.0
    [m]
    DC
    STATOI
    3951.0
    [m]
    DC
    STATOI
    3957.0
    [m]
    DC
    STATOI
    3963.0
    [m]
    DC
    STATOI
    3969.0
    [m]
    DC
    STATOI
    3975.0
    [m]
    DC
    STATOI
    3981.0
    [m]
    DC
    STATOI
    3987.0
    [m]
    DC
    STATOI
    3993.0
    [m]
    DC
    STATOI
    3999.0
    [m]
    DC
    STATOI
    4005.0
    [m]
    DC
    STATOI
    4011.0
    [m]
    DC
    STATOI
    4013.0
    [m]
    DC
    STATOI
    4023.0
    [m]
    DC
    STATOI
    4029.0
    [m]
    DC
    STATOI
    4035.0
    [m]
    DC
    STATOI
    4041.0
    [m]
    DC
    STATOI
    4047.0
    [m]
    DC
    STATOI
    4053.0
    [m]
    DC
    STATOI
    4059.0
    [m]
    DC
    STATOI
    4065.0
    [m]
    DC
    STATOI
    4071.0
    [m]
    DC
    STATOI
    4077.0
    [m]
    DC
    STATOI
    4083.0
    [m]
    DC
    STATOI
    4089.0
    [m]
    DC
    STATOI
    4095.0
    [m]
    DC
    STATOI
    4101.0
    [m]
    DC
    STATOI
    4107.0
    [m]
    DC
    STATOI
    4119.0
    [m]
    DC
    STATOI
    4125.0
    [m]
    DC
    STATOI
    4131.0
    [m]
    DC
    STATOI
    4137.0
    [m]
    DC
    STATOI
    4143.0
    [m]
    DC
    STATOI
    4149.0
    [m]
    DC
    STATOI
    4155.0
    [m]
    DC
    STATOI
    4161.0
    [m]
    DC
    STATOI
    4167.0
    [m]
    DC
    STATOI
    4173.0
    [m]
    DC
    STATOI
    4175.0
    [m]
    DC
    STATOI

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.38

  • Documents – reported by the production licence (period for duty of secrecy expired)
    Documents – reported by the production licence (period for duty of secrecy expired)
    Document name
    Document format
    Document size [MB]
    .pdf
    3.28
    .pdf
    14.80

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    HRLA DSI IPLT
    3380
    3864
    HRLA IPLT
    3760
    4175
    MDT GR
    3656
    3752
    MDT GR
    3656
    3752
    MDT GR
    3668
    3668
    MDT GR
    3675
    3719
    MDT GR
    3685
    3685
    MDT GR
    3692
    3707
    MDT GR
    3694
    3694
    MDT GR
    3694
    3694
    MDT GR
    3807
    3833
    MDT GR
    3843
    4157
    MSCT
    3655
    3833
    MWD LWD - EWR-P4 DGR SLD CNT
    3867
    4175
    MWD LWD - MPR
    359
    3867
    VSP - ASI GR
    340
    3775

  • 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
    357.0
    36
    459.0
    0.00
    LOT
    SURF.COND.
    13 3/8
    1773.0
    17 1/2
    1780.0
    1.83
    LOT
    INTERM.
    9 5/8
    2897.0
    12 1/4
    1903.0
    1.85
    LOT
    INTERM.
    7
    3647.0
    8 1/2
    3654.0
    1.49
    LOT
    OPEN HOLE
    4175.0
    6
    4175.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    459
    1.03
    sea water
    1780
    1.20
    sea water
    2903
    1.75
    versavert
    3654
    1.66
    versavert
    4175
    1.22
    glydrill

  • 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
    0.22