Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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21.11.2024 - 01:28
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6406/9-2

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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.
    6406/9-2
    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.
    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.
    6406/9-2
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    HW95M in line:4308 TRACE= x-line :2076
    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.
    1129-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.
    147
    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,
    05.02.2007
    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.
    01.07.2007
    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.
    01.07.2009
    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.
    28.06.2009
    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
    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.
    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
    3rd level with HC, age
    Age of lithostratigraphic unit, 3rd level, where hydrocarbons were encountered. Examples of legal values: CRETACEOUS, EARLY CRETACEOUS, LATE JURASSIC, EOCENE.
    EARLY JURASSIC
    3rd level with HC, formation
    Name of lithostartigraphic unit, 3rd 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.
    TOFTE FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    18.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    299.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    5348.0
    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).
    5347.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    4.7
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    184
    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.
    ÅRE FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    64° 28' 34.83'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    6° 48' 9.46'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7152101.79
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    394366.07
    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.
    5454

  • Wellbore history
    General
    The Onyx South West Appraisal Well 6406/9-2 was drilled to appraise the Onyx South West gas discovery made in 2005. Onyx is situated west of the Draugen and north-west of the Njord Fields in the southern Haltenbanken area. The well was drilled about 3.5 km NNW of the Onyx SW Exploration Well 6406/9-1, which discovered gas in a Lower to Middle Jurassic fault block. The main objective of this well was to decrease the volumetric uncertainty of the Onyx SW gas discovery by penetrating the expected FWL of the Ile Formation and deeper reservoirs at structural spill point.
    Operations and results
    Well 6406/9-2 was spudded with the semi-submersible installation West Alpha on 5 February 2007 and drilled to TD at 5348 m in Early Jurassic sediments of the Åre Formation. Prior to logging in the 12 1/4" hole there was an incident onboard the rig with fire in the engine room. The well was shut in on the Shear rams and wedge locked. After a full muster was achieved, the fire was put out with Inergen and the situation brought under control. Apart from this there were no serious technical problems in the operations. The well was drilled with spud mud down to 1450 m, with Ultradril KCl/glycol mud from 1450 m to 2410 m, and with oil based Paratherm mud from 2410 m to TD.
    Wire line logs were successfully acquired in the 17 1/2" section over the Kai, Brygge and Tare formations, with some noteworthy results. The neutron density indicated exceptionally high porosity in the base of the Kai -approaching 50 %. This is higher than should be normally possible, and implies the rock is not grain supported. The relationship between compressional and shear sonic changes dramatically in the Brygge relative to the Kai and Tare formations.
    Top Viking Group was encountered at 4325 m with 70 m Spekk Formation and 242 m of Melke Formation. The Fangst Group was encountered at 4637 m. The Garn formation is not a reservoir in the area. Low reservoir quality heterogeneous sands characterised by cemented streaks and clay layers, were observed in the upper Ile and upper and middle Tilje Formations. The lower part of the middle Tilje appeared to exhibit some higher reservoir quality. Very high reservoir quality was observed in both the Lower Ile and Lower Tilje, which were both cored. The Ile Formation was fully hydrocarbon bearing, with two gas-down to contacts; at 4814 m in the upper Ile and at 4850 m in the lower Ile Formation. There were indications that the Ile contains an intra-formational seal, thereby explaining the two contacts encountered. The upper Tilje and upper part of the middle Tilje Formations were also gas bearing. A gas-down-to contact was observed in the Middle Tilje at 5126 m, with water present in the lower part of the Middle Tilje. The Lower Tilje was water bearing. The Tofte Formation contained both tight (possibly gas bearing) and high quality water bearing sands layers.
    Four cores were cut. Core 1 was cut at 4828 - 4857.1 m in lower Ile Formation, core 2 was cut at 5096- 5100.3 m in upper Tilje Formation, core 3 was cut at 5103 - 5134.5 m in middle Tilje Formation, and core 4 was cut at 5209.7 - 5236.9 m in lower Tilje Formation. MDT fluid samples were taken at 4827 m in lower Ile Formation (gas) and 5206 m in lower Tilje Formation (water).
    The well was permanently abandoned on 1 July 2007 as a gas appraisal 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]
    1460.00
    5348.00

  • 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
    4828.0
    4857.1
    [m ]
    2
    5096.0
    5100.3
    [m ]
    3
    5103.0
    5134.5
    [m ]
    4
    5209.7
    5236.8
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    91.9
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.86

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL
    2517
    4446
    GPIT PPC DSI PPC PEX ACTS ECRD
    1443
    2406
    IS PPC DSI AIT IPLT GR ACTS ECRD
    3507
    4430
    MDT GR
    4070
    4098
    MDT GR
    4070
    4098
    MDT GR KEH ECRI
    4826
    5125
    MDT GR LEH ECRI
    4766
    5125
    MDT GR LEH ECRI
    4766
    4850
    MDT GR LEH ECRI
    4795
    5235
    MDT GR LEH ECRI
    4811
    4826
    MDT GR LEH ECRI
    5206
    5206
    MWD - GR
    317
    404
    MWD ARC - GR RES APWD
    402
    5333
    QAIT QSLT QLDT QCNT ECS HR LEH
    4458
    5327
    QAIT QSLT QLDT QCNT ECS HR LEH
    4458
    5327
    STETOSCOPE
    4754
    4789
    VSI
    1087
    4571

  • 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
    402.0
    36
    407.0
    0.00
    LOT
    SURF.COND.
    20
    1443.0
    26
    1450.0
    1.75
    LOT
    INTERM.
    13 3/8
    2404.0
    17 1/2
    2410.0
    1.90
    LOT
    INTERM.
    9 5/8
    4456.0
    12 1/4
    4461.0
    0.00
    LOT
    OPEN HOLE
    5348.0
    8 1/2
    5348.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    707
    1.75
    21.0
    OTHER
    2353
    1.84
    53.0
    PARATHERM
    4461
    1.84
    39.0
    PARATHERM
    4523
    1.84
    43.0
    PARATHERM
    4640
    1.84
    39.0
    PARATHERM
    4864
    1.84
    44.0
    PARATHERM
    5097
    1.84
    44.0
    PARATHERM
    5103
    1.84
    44.0
    PARATHERM
    5133
    1.84
    48.0
    PARATHERM
    5182
    1.84
    46.0
    PARATHERM
    5239
    1.84
    51.0
    PARATHERM
    5254
    1.84
    47.0
    PARATHERM
    5348
    1.85
    48.0
    PARATHERM