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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6405/10-1

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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.
    6405/10-1
    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.
    6405/10-1
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    ST04M01 & inline 2913 & crossline 2838
    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.
    1145-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.
    65
    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,
    05.07.2007
    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.
    07.09.2007
    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.
    07.09.2009
    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.
    06.09.2009
    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.
    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.
    LATE CRETACEOUS
    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.
    NISE FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    23.5
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    928.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3182.0
    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).
    3182.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    1.2
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    94
    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.
    LATE CRETACEOUS
    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.
    NISE FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    64° 0' 49.1'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    5° 16' 45.8'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7100701.88
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    611423.07
    UTM zone
    Universal Transverse Mercator zone. Examples of legal values: 31, 32, 33, 34.
    31
    NPDID wellbore
    Norwegian Offshore Directorate's unique id for the wellbore.
    5565

  • Wellbore history
    General
    Block 6405/10 is located along the Jan-Mayen Lineament in the Norwegian Sea, in the transition zone between the Møre Basin in the south and the Vøring Basin in the north. Well 6405/10-1 is located half-way between the Ormen Lange and the Ellida discoveries. The primary well objective was to prove the presence of reservoir quality sandstone and hydrocarbons in the Midnattsol prospect. The primary target was deep marine sandstones of Campanian age in the Late Cretaceous Nise Formation. In addition, understanding the origin of the associated seismic flat event was an important objective for this well.
    Operations and results
    Wildcat well 6405/10-1 was spudded with the semi-submersible installation Transocean Leader on 5 July 2007 and drilled vertically through Quaternary, Tertiary and Late Cretaceous Formations to TD at 3182 m in the Late Cretaceous Nise Formation. A 9 7/8" pilot hole, designated 6405/10-U-1, was drilled to a total depth of 1850 prior to drilling the main hole. The objective of the pilot hole was to detect shallow water flows in the Naust Formation, in addition to acquiring good quality logging data of the upper section. Well 6405/10-1 was spudded 50 m from the pilot hole location in 928 m water depth. No significant technical problems were encountered during the operations. The well was drilled with seawater and sweeps down to 1760 m, with PERFORMADRIL water based mud from 1760 to 2442 m, and with INNOVERT paraffin/mineral oil based mud from 2442 m to TD. The oil base was analysed to be composed of hydrocarbons in the C11 to C16 range.
    The Nise Formation was penetrated at 2937 m and consisted of bioturbated deep marine sandstones, siltstones and shales. The Nise Formation held a hydrocarbon column of approximately 60 m, but the reservoir properties were poor. The hydrocarbon column corresponded with the structural closure, but lied appreciably shallower than the mapped flat event, which suggested a hydrocarbon column of 140 m. The well results did not resolve whether the flat event is related to fluids (residual gas saturation) or to diagenetic changes. No oil shows were recorded in the well, or from post-well organic geochemical analyses. Very high levels of gas were recorded in the interval 2779 - 2808 m (Tang Formation - Egga Informal Formation). The fluid comprised of over 94% C1 (based on average C1 to C4% composition). The mud weight was increase from 1.48 sg to 1.54 sg while circulating this gas out. Significant gas levels were recorded in the interval 2935 to 3004 m containing a similar fluid composition.
    Two cores were cut from 3004 to 3035 m. Extensive wire line data acquisition was performed, including MDT pressure testing and sidewall cores. Hydrocarbon gas samples were collected at 2951.5 m and 2994.4 m and a water sample was collected at 3049.2 m.
    The well was permanently abandoned on 7 September 2007 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]
    1770.00
    3180.00

  • 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
    3004.0
    3014.0
    [m ]
    2
    3014.0
    3035.2
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    31.2
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Lithostratigraphy
    Lithostratigraphy
    Top depth [mMD RKB]
    Lithostrat. unit
    952
    952
    1891
    1891
    2568
    2568
    2723
    2783
    2811
    2811
    2937

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.43

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.23
    pdf
    1.01
    pdf
    0.22

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    AIT PEX ACTS ECRD
    2808
    3033
    AIT PEX ECS HNGS ACTS ECRD
    2808
    3185
    CMR BFV
    2808
    3185
    DSI HRLA PEX ACTS ECRD
    1749
    2420
    GAUGERUN
    952
    3049
    MDT GR
    2808
    3033
    MDT PA PS
    2942
    3051
    MDT PA PS
    2962
    3025
    MSCT GR
    2800
    3046
    MWD - PP AC T
    3004
    3182
    MWD - PP AV
    952
    2442
    MWD - PP AV SADN8 SV GVR8 SS
    2442
    2808
    MWD - PP ES SS GVR
    2808
    3004
    OBMI MSIP ACTS ECRD
    2808
    3185
    VSP NI VSI4
    3884
    4104

  • 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
    1041.0
    36
    1045.0
    0.00
    LOT
    SURF.COND.
    20
    1749.0
    26
    1760.0
    1.39
    LOT
    INTERM.
    13 3/8
    2423.0
    17 1/4
    2442.0
    1.56
    LOT
    INTERM.
    9 5/8
    2799.0
    12 1/4
    2808.0
    1.63
    LOT
    OPEN HOLE
    3182.0
    8 1/2
    3182.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    1017
    1.03
    SEAWATER
    1045
    1.35
    12.0
    SPUD MUD
    1230
    1.35
    12.0
    SPUD MUD
    1760
    1.35
    12.0
    SPUD MUD
    1951
    1.12
    8.0
    HPWBM
    2356
    1.29
    11.0
    HPWBM
    2442
    1.34
    14.0
    HPWBM
    2801
    1.55
    35.0
    OBM-HTHP
    2808
    1.53
    33.0
    OBM-HTHP

  • Thin sections at the Norwegian Offshore Directorate
    Thin sections at the Norwegian Offshore Directorate
    Depth
    Unit
    3014.13
    [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