Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
25.11.2024 - 01:30
Time of last synchronization with Norwegian Offshore Directorate's internal systems

6406/9-3

Export: PDF icon PDF

  • General information
    General information
    Attribute Value
    Wellbore name
    Official name of wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    6406/9-3
    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
    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.
    6406/9-3
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    SH0902MZ10.inline 5601 & crossline 3096
    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.
    A/S Norske Shell
    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.
    1439-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.
    165
    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,
    18.04.2013
    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.
    29.09.2013
    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.
    29.09.2015
    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.
    29.09.2015
    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.
    ILE FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    40.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    298.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    5138.0
    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).
    5135.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    6.6
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    186
    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° 25' 15.99'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    6° 58' 42.79'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7145667.70
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    402625.05
    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.
    7141

  • Wellbore history
    General
    Well 6406/9-3 was drilled on the Onyx prospect between the Linnorm, Mjøsa and Noatun discoveries in the southern part of the Halten Terrace in the Norwegian Sea. The primary objective was to prove petroleum in the Middle to Early Jurassic sequence (Ile, Tofte, and Tilje formations. The secondary objective was to evaluate potential Åre Formation reservoirs.
    Operations and results
    Wildcat well 6406/9-3 was spudded with the semi-submersible installation Transocean Barents on 18 April 2013 and drilled to TD at 5138 m in the Early Jurassic Tilje Formation. No shallow gas was observed by the ROV at the wellhead or the MWD while drilling the 9-7/8'' pilot hole to a planned depth of 637 m. During drilling of the 26'' section at 1288 m a minor shallow water flow with some gas bubbles was observed at the wellhead and it was recognised that the Kai Formation was penetrated underbalanced. It was decided to set the 20'' casing shallow. Low leak-off at the 20'' shoe required running a 16'' contingency liner. The 14 3/4" x 17 1/2" section was drilled to section TD at 2270 m. A bad cement job around the 13 5/8" casing caused a technical sidetrack from 1645 m. The sidetrack is named 6406/9-3 T2. While drilling the basal part of the lower Cretaceous Lange Formation the interpreted real-time pore pressure exceeded the pre-drill high-case prediction and consequently the 10'' casing was set shallower than planned. The well was drilled with seawater and hi-vis sweeps down to 1288 m, with Glydril mud from 1288 m to 2294 m in both well tracks, and with EMS-400 oil based mud from 2294 m to TD.
    The well penetrated the two primary reservoir targets of Jurassic age: the Ile Formation at 4635 m and the Tilje Formation at 4954 m. A non-commercial gas reservoir was evaluated in the Ile Formation. The free water level is indicated to be between 4695 and 4704 m based mainly on the mixed gas and water in the MDT sample at 4697 m. The Upper/Middle Tilje Formations was found to be tight and residual gas bearing, while the Lower Tilje Formation was confirmed water bearing. Due to the non-commercial discovery in the primary target, the Åre Formation was not drilled. Oil shows were described on the core in the Ile Formation. On cuttings, there were no shows that could be distinguished from the oil based mud.
    One 27m core was taken in the Lower Ile Formation from 4704 m to 4731 m with 99.9% recovery.  MDT fluid samples were taken at 4697 m (water and gas) and at 4715.4 m (water). Both samples had mud filtrate contamination.
    The well was permanently abandoned on 29 September 2013 as a minor 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]
    1298.00
    2268.00

  • 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
    4704.0
    4731.0
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    27.0
    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
    1650.0
    [m]
    DC
    SHELL
    1670.0
    [m]
    DC
    SHELL
    1690.0
    [m]
    DC
    SHELL
    1710.0
    [m]
    DC
    SHELL
    1750.0
    [m]
    DC
    SHELL
    1770.0
    [m]
    DC
    SHELL
    1790.0
    [m]
    DC
    SHELL
    1810.0
    [m]
    DC
    SHELL
    1830.0
    [m]
    DC
    SHELL
    1850.0
    [m]
    DC
    SHELL
    1870.0
    [m]
    DC
    SHELL
    1890.0
    [m]
    DC
    SHELL
    1910.0
    [m]
    DC
    SHELL
    1930.0
    [m]
    DC
    SHELL
    1950.0
    [m]
    DC
    SHELL
    1970.0
    [m]
    DC
    SHELL
    1990.0
    [m]
    DC
    SHELL
    2010.0
    [m]
    DC
    SHELL
    2030.0
    [m]
    DC
    SHELL
    2050.0
    [m]
    DC
    SHELL
    2070.0
    [m]
    DC
    SHELL
    2090.0
    [m]
    DC
    SHELL
    2110.0
    [m]
    DC
    SHELL
    2120.0
    [m]
    DC
    SHELL
    2130.0
    [m]
    DC
    SHELL
    2150.0
    [m]
    DC
    SHELL
    2170.0
    [m]
    DC
    SHELL
    2190.0
    [m]
    DC
    SHELL
    2210.0
    [m]
    DC
    SHELL
    2230.0
    [m]
    DC
    SHELL
    2240.0
    [m]
    DC
    SHELL
    2250.0
    [m]
    DC
    SHELL
    2270.0
    [m]
    DC
    SHELL
    2290.0
    [m]
    DC
    SHELL
    2310.0
    [m]
    DC
    SHELL
    2330.0
    [m]
    DC
    SHELL
    2350.0
    [m]
    DC
    SHELL
    2370.0
    [m]
    DC
    SHELL
    2390.0
    [m]
    DC
    SHELL
    2410.0
    [m]
    DC
    SHELL
    2430.0
    [m]
    DC
    SHELL
    2450.0
    [m]
    DC
    SHELL
    2470.0
    [m]
    DC
    SHELL
    2490.0
    [m]
    DC
    SHELL
    2510.0
    [m]
    DC
    SHELL
    2530.0
    [m]
    DC
    SHELL
    2550.0
    [m]
    DC
    SHELL
    2570.0
    [m]
    DC
    SHELL
    2590.0
    [m]
    DC
    SHELL
    2610.0
    [m]
    DC
    SHELL
    2630.0
    [m]
    DC
    SHELL
    2650.0
    [m]
    DC
    SHELL
    2670.0
    [m]
    DC
    SHELL
    2690.0
    [m]
    DC
    SHELL
    2710.0
    [m]
    DC
    SHELL
    2730.0
    [m]
    DC
    SHELL
    2750.0
    [m]
    DC
    SHELL
    2770.0
    [m]
    DC
    SHELL
    2790.0
    [m]
    DC
    SHELL
    2810.0
    [m]
    DC
    SHELL
    2830.0
    [m]
    DC
    SHELL
    2850.0
    [m]
    DC
    SHELL
    2870.0
    [m]
    DC
    SHELL
    2890.0
    [m]
    DC
    SHELL
    2910.0
    [m]
    DC
    SHELL
    2930.0
    [m]
    DC
    SHELL
    2950.0
    [m]
    DC
    SHELL
    2970.0
    [m]
    DC
    SHELL
    2990.0
    [m]
    DC
    SHELL
    3010.0
    [m]
    DC
    SHELL
    3030.0
    [m]
    DC
    SHELL
    3050.0
    [m]
    DC
    SHELL
    3070.0
    [m]
    DC
    SHELL
    3090.0
    [m]
    DC
    SHELL
    3110.0
    [m]
    DC
    SHELL
    3130.0
    [m]
    DC
    SHELL
    3150.0
    [m]
    DC
    SHELL
    3170.0
    [m]
    DC
    SHELL
    3190.0
    [m]
    DC
    SHELL
    3210.0
    [m]
    DC
    SHELL
    3230.0
    [m]
    DC
    SHELL
    3250.0
    [m]
    DC
    SHELL
    3270.0
    [m]
    DC
    SHELL
    3290.0
    [m]
    DC
    SHELL
    3310.0
    [m]
    DC
    SHELL
    3330.0
    [m]
    DC
    SHELL
    3341.0
    [m]
    DC
    SHELL
    3355.0
    [m]
    DC
    SHELL
    3370.0
    [m]
    DC
    SHELL
    3390.0
    [m]
    DC
    SHELL
    3410.0
    [m]
    DC
    SHELL
    3430.0
    [m]
    DC
    SHELL
    3450.0
    [m]
    DC
    SHELL
    3470.0
    [m]
    DC
    SHELL
    3490.0
    [m]
    DC
    SHELL
    3510.0
    [m]
    DC
    SHELL
    3530.0
    [m]
    DC
    SHELL
    3550.0
    [m]
    DC
    SHELL
    3570.0
    [m]
    DC
    SHELL
    3590.0
    [m]
    DC
    SHELL
    3610.0
    [m]
    DC
    SHELL
    3630.0
    [m]
    DC
    SHELL
    3650.0
    [m]
    DC
    SHELL
    3670.0
    [m]
    DC
    SHELL
    3690.0
    [m]
    DC
    SHELL
    3710.0
    [m]
    DC
    SHELL
    3730.0
    [m]
    DC
    SHELL
    3750.0
    [m]
    DC
    SHELL
    3770.0
    [m]
    DC
    SHELL
    3790.0
    [m]
    DC
    SHELL
    3810.0
    [m]
    DC
    SHELL
    3830.0
    [m]
    DC
    SHELL
    3850.0
    [m]
    DC
    SHELL
    3870.0
    [m]
    DC
    SHELL
    3890.0
    [m]
    DC
    SHELL
    3910.0
    [m]
    DC
    SHELL
    3930.0
    [m]
    DC
    SHELL
    3950.0
    [m]
    DC
    SHELL
    3970.0
    [m]
    DC
    SHELL
    3990.0
    [m]
    DC
    SHELL
    4010.0
    [m]
    DC
    SHELL
    4030.0
    [m]
    DC
    SHELL
    4050.0
    [m]
    DC
    SHELL
    4070.0
    [m]
    DC
    SHELL
    4090.0
    [m]
    DC
    SHELL
    4110.0
    [m]
    DC
    SHELL
    4130.0
    [m]
    DC
    SHELL
    4150.0
    [m]
    DC
    SHELL
    4170.0
    [m]
    DC
    SHELL
    4190.0
    [m]
    DC
    SHELL
    4210.0
    [m]
    DC
    SHELL
    4230.0
    [m]
    DC
    SHELL
    4248.0
    [m]
    DC
    SHELL
    4266.0
    [m]
    DC
    SHELL
    4284.0
    [m]
    DC
    SHELL
    4302.0
    [m]
    DC
    SHELL

  • Lithostratigraphy

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL VDL CCL GR
    1550
    2255
    MWD - DIR
    0
    456
    MWD - RES GR DIR
    456
    2270
    MWD - SON DEN POR GR DIR
    456
    637

  • 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
    36
    45.0
    42
    0.0
    0.00
    CONDUCTOR
    36
    450.0
    42
    455.0
    0.00
    SURF.COND.
    20
    1284.0
    26
    1288.0
    1.58
    LOT
    INTERM.
    16
    1605.0
    20
    1608.0
    1.76
    LOT
    INTERM.
    13 3/8
    2261.0
    17 1/2
    2270.0
    1.91
    FIT
    OPEN HOLE
    2273.0
    12 1/4
    2273.0
    0.00

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    40
    1.03
    Seawater
    40
    1.37
    KPM KCl Polymer
    456
    1.20
    KPM KCl Polymer
    466
    1.37
    KPM KCl Polymer
    1288
    1.37
    KPM KCl Polymer
    1288
    1.50
    Glydril
    1400
    1.52
    Glydril
    1580
    1.55
    Glydril
    1608
    1.55
    Glydril
    1765
    1.75
    Glydril
    2270
    1.80
    EMS-4400
    2270
    1.75
    Glydril
    2294
    1.73
    Glydril
    2297
    1.80
    Oil Based
    3626
    1.86
    EMS-4400
    4086
    1.83
    EMS-4400
    4331
    1.94
    EMS-4400
    4704
    1.86
    EMS-4400
    5113
    1.86
    EMS-4400
    5138
    1.86
    EMS-4400