Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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25.11.2024 - 01:30
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6507/11-6

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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.
    6507/11-6
    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.
    6507/11-6
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    Survey: inline 4475-crossline 2790
    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.
    Norsk Hydro Produksjon AS
    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.
    1005-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.
    26
    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,
    13.06.2001
    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.
    08.07.2001
    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.
    08.07.2003
    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.
    28.06.2007
    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/CONDENSATE
    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.
    GARN 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.
    291.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3440.0
    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).
    3439.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    3.8
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    115
    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.
    65° 1' 9.02'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    7° 24' 52.17'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7211708.74
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    425288.63
    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.
    4321

  • Wellbore history
    General
    Exploration well 6507/11-6 was drilled on the Colette structure, a downfaulted structure west of the Midgard Field in the Haltenbanken area. The primary objectives of the well were to test the hydrocarbon potential of the Middle Jurassic Garn and Ile Formations. A stratigraphical trap at top Lysing Formation level and possible hydrocarbon trapping in the uppermost part of the Early Jurassic Tilje were secondary targets.
    Operations and results
    Wildcat well 6507/11-6 was spudded with the semi-submersible installation Transocean Arctic on 30 June 2001 and drilled to TD at 3440 m in Late Jurassic sediments of the Åre Formation. The 36" and 26" hole sections down to 489 m were drilled with seawater, the 17 1/2" section down to 1283 m with water-based KCL mud, and the remaining 12 1/4" and 8 1/2" hole down to TD was drilled with Versavert oil-based drilling mud. No shallow gas was encountered in the well, in accordance with the weak shallow gas warning in the pre-drill well documentation.
    The main result of the well was the discovery of a 30 m column of gas from the top of the Middle Jurassic Garn Formation at 3030 m. A gas-water contact in the Garn Formation was interpreted at 3059.5 m (3035.0 m TVD MSL). A pressure gradient of 0.22 g/cc (similar to Midgard) within the gas zone was defined by good quality MDT pressure measurements. Pressure data indicated small pressure barriers between the Garn, Ile, and Tilje Formations. However, the sandstones in lower part of the Garn Formation as well as the sandstones in the Ile, Tilje and Åre Formations were all water bearing. There were no Lysing Formation sandstones in the well position.
    One core was cut covering 27.6 m of the 47 m thick Garn Formation. The core contained almost 100% clean sandstone and the reservoir quality was excellent. There were very good reservoir quality sandstones also in the Ile, Tilje and Åre Formations. A total of 27 rotary sidewall cores were recovered (100% recovery) from the Jurassic section. Fluid samples were obtained from three levels within the Garn Formation.
    The well was permanently abandoned on 8 July 2001 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]
    460.00
    3440.00

  • 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
    3036.0
    3063.7
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    27.7
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 3036-3041m
    Core photo at depth: 3041-3046m
    Core photo at depth: 3046-3051m
    Core photo at depth: 3051-3056m
    Core photo at depth: 3056-3061m
    3036-3041m
    3041-3046m
    3046-3051m
    3051-3056m
    3056-3061m
    Core photo at depth: 3061-3063m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    3061-3063m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    460.0
    [m]
    DC
    RRI
    500.0
    [m]
    DC
    RRI
    540.0
    [m]
    DC
    RRI
    580.0
    [m]
    DC
    RRI
    620.0
    [m]
    DC
    RRI
    660.0
    [m]
    DC
    RRI
    700.0
    [m]
    DC
    RRI
    740.0
    [m]
    DC
    RRI
    780.0
    [m]
    DC
    RRI
    1380.0
    [m]
    DC
    RRI
    1540.0
    [m]
    DC
    RRI
    1580.0
    [m]
    DC
    RRI
    1620.0
    [m]
    DC
    RRI
    1660.0
    [m]
    DC
    RRI
    1700.0
    [m]
    DC
    RRI
    1740.0
    [m]
    DC
    RRI
    1780.0
    [m]
    DC
    RRI
    1820.0
    [m]
    DC
    RRI
    1860.0
    [m]
    DC
    RRI
    1900.0
    [m]
    DC
    RRI
    1940.0
    [m]
    DC
    RRI
    1980.0
    [m]
    DC
    RRI
    2020.0
    [m]
    DC
    RRI
    2060.0
    [m]
    DC
    RRI
    2100.0
    [m]
    DC
    RRI
    2140.0
    [m]
    DC
    RRI
    2170.0
    [m]
    DC
    RRI
    2190.0
    [m]
    DC
    RRI
    2230.0
    [m]
    DC
    RRI
    2250.0
    [m]
    DC
    RRI
    2270.0
    [m]
    DC
    RRI
    2290.0
    [m]
    DC
    RRI
    2310.0
    [m]
    DC
    RRI
    2330.0
    [m]
    DC
    RRI
    2350.0
    [m]
    DC
    RRI
    2370.0
    [m]
    DC
    RRI
    2390.0
    [m]
    DC
    RRI
    2410.0
    [m]
    DC
    RRI
    2430.0
    [m]
    DC
    RRI
    2450.0
    [m]
    DC
    RRI
    2470.0
    [m]
    DC
    RRI
    2490.0
    [m]
    DC
    RRI
    2510.0
    [m]
    DC
    RRI
    2530.0
    [m]
    DC
    RRI
    2550.0
    [m]
    DC
    RRI
    2570.0
    [m]
    DC
    RRI
    2590.0
    [m]
    DC
    RRI
    2610.0
    [m]
    DC
    RRI
    2630.0
    [m]
    DC
    RRI
    2650.0
    [m]
    DC
    RRI
    2670.0
    [m]
    DC
    RRI
    2690.0
    [m]
    DC
    RRI
    2710.0
    [m]
    DC
    RRI
    2730.0
    [m]
    DC
    RRI
    2750.0
    [m]
    DC
    RRI
    2770.0
    [m]
    DC
    RRI
    2790.0
    [m]
    DC
    RRI
    2810.0
    [m]
    DC
    RRI
    2830.0
    [m]
    DC
    RRI
    2850.0
    [m]
    DC
    RRI
    2870.0
    [m]
    DC
    RRI
    2890.0
    [m]
    DC
    RRI
    2910.0
    [m]
    DC
    RRI
    2930.0
    [m]
    DC
    RRI
    2950.0
    [m]
    DC
    RRI
    2970.0
    [m]
    DC
    RRI
    2985.0
    [m]
    DC
    RRI
    2995.0
    [m]
    DC
    RRI
    3005.0
    [m]
    DC
    RRI
    3015.0
    [m]
    DC
    RRI
    3025.0
    [m]
    DC
    RRI
    3030.0
    [m]
    DC
    RRI
    3035.0
    [m]
    DC
    RRI
    3042.6
    [m]
    DC
    RRI
    3065.0
    [m]
    DC
    RRI
    3070.0
    [m]
    DC
    RRI
    3075.0
    [m]
    DC
    RRI
    3080.0
    [m]
    DC
    RRI
    3085.0
    [m]
    DC
    RRI
    3090.0
    [m]
    DC
    RRI
    3095.0
    [m]
    DC
    RRI
    3100.0
    [m]
    DC
    RRI
    3105.0
    [m]
    DC
    RRI
    3110.0
    [m]
    DC
    RRI
    3115.0
    [m]
    DC
    RRI
    3120.0
    [m]
    DC
    RRI
    3125.0
    [m]
    DC
    RRI
    3130.0
    [m]
    DC
    RRI
    3135.0
    [m]
    DC
    RRI
    3140.0
    [m]
    DC
    RRI
    3145.0
    [m]
    DC
    RRI
    3150.0
    [m]
    DC
    RRI
    3155.0
    [m]
    DC
    RRI
    3165.0
    [m]
    DC
    RRI
    3175.0
    [m]
    DC
    RRI
    3185.0
    [m]
    DC
    RRI
    3195.0
    [m]
    DC
    RRI
    3205.0
    [m]
    DC
    RRI
    3215.0
    [m]
    DC
    RRI
    3225.0
    [m]
    DC
    RRI
    3235.0
    [m]
    DC
    RRI
    3245.0
    [m]
    DC
    RRI
    3255.0
    [m]
    DC
    RRI
    3265.0
    [m]
    DC
    RRI
    3275.0
    [m]
    DC
    RRI
    3285.0
    [m]
    DC
    RRI
    3295.0
    [m]
    DC
    RRI
    3305.0
    [m]
    DC
    RRI
    3315.0
    [m]
    DC
    RRI
    3325.0
    [m]
    DC
    RRI
    3335.0
    [m]
    DC
    RRI
    3345.0
    [m]
    DC
    RRI
    3355.0
    [m]
    DC
    RRI
    3365.0
    [m]
    DC
    RRI
    3375.0
    [m]
    DC
    RRI
    3385.0
    [m]
    DC
    RRI
    3395.0
    [m]
    DC
    RRI
    3405.0
    [m]
    DC
    RRI
    3415.0
    [m]
    DC
    RRI
    3425.0
    [m]
    DC
    RRI
    3435.0
    [m]
    DC
    RRI

  • Lithostratigraphy

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    2.90

  • 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
    7.47
    .pdf
    5.80

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CMST GR
    2982
    3398
    DSI GR ACTS
    2075
    3440
    MDT GR - PRESS
    3034
    3398
    MDT GR - SAMPLE
    3034
    3075
    MWD
    315
    377
    MWD - CDR
    377
    1608
    MWD - CDR ISON CDN
    1608
    2917
    MWD - VISION ADN RAB
    2917
    3440
    ZO VSP DUAL CSAT
    2140
    3400

  • 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
    375.0
    36
    375.0
    0.00
    LOT
    SURF.COND.
    20
    454.0
    26
    459.0
    1.41
    LOT
    INTERM.
    13 3/8
    1602.0
    17 1/2
    1608.0
    1.81
    LOT
    INTERM.
    9 5/8
    2913.0
    12 1/4
    1917.0
    1.45
    LOT
    OPEN HOLE
    3340.0
    8 1/2
    3340.0
    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
    WATER BASED
    1250
    1.60
    36.0
    OIL BASED
    1608
    1.30
    15.0
    WATER BASED
    2242
    1.60
    38.0
    OIL BASED
    2917
    1.60
    43.0
    OIL BASED
    3385
    1.25
    25.0
    OIL BASED

  • 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
    0.29