Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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31.10.2024 - 01:27
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6507/7-11 S

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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.
    6507/7-11 S
    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
    Multilateral
    Indicator telling if the parent well is multilateral, meaning it has more than one branch radiating from the main borehole. Example of legal values: YES, NO. See also Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    NO
    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
    Well name
    Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    6507/7-11
    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.
    Conoco Norway Inc.
    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.
    897-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.
    51
    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,
    25.06.1997
    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.
    14.08.1997
    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.
    14.08.1999
    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.
    18.05.2004
    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.
    WILDCAT
    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.
    DRY
    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
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    23.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    274.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3749.0
    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).
    3744.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    7.8
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    127
    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° 18' 4.8'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    7° 7' 42.27'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7243514.99
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    412743.08
    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.
    3131

  • Wellbore history
    General
    Well 6507/7-11 S was drilled to test a 3-way dip closed structure (Heidrun SW) between the Smørbukk Field to the southwest and the Heidrun Field to the northeast. The Heidrun SW prospect consists of a downthrown fault closure, W-segment and an independent up-thrown three way dip-closure; the SW-segment. The trap is a structural hanging wall trap, and formed as a consequence of Late Jurassic to Middle Cretaceous extensional tectonics. The prospect has a 3-way dip closure to the north, west and south and an up-thrown fault closure to the east, requiring a fault seal in order to have hydrocarbons present. The primary objective was to prove up commercial reserves for the Heidrun SW structure, by testing the hydrocarbon potential of the Middle Jurassic Fangst Group, by means of wire line logging and coring. Secondary objectives were to test the Early Jurassic Tilje and Åre reservoirs and the Early Cretaceous sandstones for Hydrocarbon potential. The flowing potential and productivity of a discovery, if made, should be evaluated by MDT and DST-tools. If no indications of hydrocarbons in Late Tilje were found, the well would reach TD at 3706 m TVD RKB (3710 m MD RKB) or 50 m below top Tilje Formation. If hydrocarbons were present, the well would reach TD deeper, at 3926 m TVD RKB (3930 mMD RKB) or 270 m below top Tilje.
    Operations and results
    Well 6507/7-11 S was spudded with the semi-submersible installation Mærsk Jutlander on 25 June 1997 and drilled to TD at 3749 m (3744 m TVD RKB) in the Early Jurassic Tilje Formation. The well was drilled with Seawater and hi-vis pills down to 754 m and with KCl glycol enhanced mud from 754 m to TD.
    Nearly 40 m net thickness (of 100 m gross) of Fangst Group sandstones was encountered. Apart from elevated high background levels of mud gas in the interval 1500 m to 1540 m (7% to 11%) the well was practically devoid of hydrocarbon indications and the target reservoir zones in the Fangst and Båt Groups were found to be dry. A drill break in the Garn Formation confirmed only background levels of gas. One core was cut from the Garn Formation and into the Not Formation in the interval 3461 m to 3488 m, recovering sandstone with a siltstone bed. A PVT water sample was taken at the depth of 3458.9 m in the Garn Formation.
    The well was permanently abandoned as a dry well on 14 August 1997.
    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]
    754.00
    3749.00

  • 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
    3461.0
    3487.8
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    26.8
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 3461-3466m
    Core photo at depth: 3466-3471m
    Core photo at depth: 3471-3476m
    Core photo at depth: 3476-3481m
    Core photo at depth: 3481-3486m
    3461-3466m
    3466-3471m
    3471-3476m
    3476-3481m
    3481-3486m
    Core photo at depth: 3481-3488m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    3481-3488m

  • 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
    359.0
    36
    360.0
    0.00
    LOT
    SURF.COND.
    20
    749.0
    26
    754.0
    1.37
    LOT
    INTERM.
    13 3/8
    1987.0
    17 1/2
    1995.0
    1.92
    LOT
    INTERM.
    9 5/8
    3357.0
    12 1/4
    3365.0
    1.96
    LOT
    OPEN HOLE
    3749.0
    8 1/2
    3749.0
    0.00
    LOT

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    AIT LDT CNL HNGS DSI ACTS GR
    1987
    3365
    CST GR
    0
    0
    DSI GR AMS
    3357
    3750
    FMI GR ACTS
    3357
    3750
    LDT APS HNGS AIT ACTS
    3357
    3750
    MDT GR ACTS
    3458
    3739
    MWD
    749
    754
    MWD - DGR EWR-P4 SLD SNP
    3365
    3749
    MWD - DGR EWR-P4 SLD SNP CLSS
    1995
    3365
    MWD - DGR EWRS
    754
    1995
    ZOVSP GR
    2400
    3740

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.49

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    2.64

  • 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
    78.80

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    330
    1.20
    SPUD MUD
    680
    1.20
    SPUD MUD
    806
    1.28
    14.0
    KCL/GEM GP
    1123
    1.31
    12.0
    KCL/GEM GP
    1598
    1.27
    16.0
    KCL/GEM GP
    1987
    1.27
    14.0
    KCL/GEM GP
    2500
    1.52
    28.0
    KCL/GEM GP
    2788
    1.64
    36.0
    KCL/GEM GP
    3049
    1.64
    38.0
    KCL/GEM GP
    3061
    1.70
    36.0
    KCL/GEM GP
    3204
    1.70
    37.0
    KCL/GEM GP
    3246
    1.70
    40.0
    KCL/GEM GP
    3343
    1.68
    38.0
    KCL/GEM GP
    3365
    1.70
    33.0
    KCL/GEM GP
    3749
    1.20
    22.0
    KCL/GEM GP

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    2100.0
    [m]
    DC
    RRI
    2120.0
    [m]
    DC
    RRI
    2140.0
    [m]
    DC
    RRI
    2180.0
    [m]
    DC
    RRI
    2200.0
    [m]
    DC
    RRI
    2220.0
    [m]
    DC
    RRI
    2240.0
    [m]
    DC
    RRI
    2260.0
    [m]
    DC
    RRI
    2280.0
    [m]
    DC
    RRI
    2290.0
    [m]
    DC
    RRI
    2320.0
    [m]
    DC
    RRI
    2340.0
    [m]
    DC
    RRI
    2360.0
    [m]
    DC
    RRI
    2380.0
    [m]
    DC
    RRI
    2400.0
    [m]
    DC
    RRI
    2420.0
    [m]
    DC
    RRI
    2440.0
    [m]
    DC
    RRI
    2460.0
    [m]
    DC
    RRI
    2480.0
    [m]
    DC
    RRI
    2500.0
    [m]
    DC
    RRI
    2520.0
    [m]
    DC
    RRI
    2540.0
    [m]
    DC
    RRI
    2560.0
    [m]
    DC
    RRI
    2580.0
    [m]
    DC
    RRI
    2600.0
    [m]
    DC
    RRI
    2620.0
    [m]
    DC
    RRI
    2640.0
    [m]
    DC
    RRI
    2660.0
    [m]
    DC
    RRI
    2680.0
    [m]
    DC
    RRI
    2700.0
    [m]
    DC
    RRI
    2720.0
    [m]
    DC
    RRI
    2730.0
    [m]
    DC
    RRI
    2760.0
    [m]
    DC
    RRI
    2780.0
    [m]
    DC
    RRI
    2800.0
    [m]
    DC
    RRI
    2810.0
    [m]
    DC
    RRI
    2815.0
    [m]
    DC
    RRI
    2820.0
    [m]
    DC
    RRI
    2825.0
    [m]
    DC
    RRI
    2835.0
    [m]
    DC
    RRI
    2845.0
    [m]
    DC
    RRI
    2850.0
    [m]
    DC
    RRI
    2855.0
    [m]
    DC
    RRI
    2860.0
    [m]
    DC
    RRI
    2865.0
    [m]
    DC
    RRI
    2880.0
    [m]
    DC
    RRI
    2885.0
    [m]
    DC
    RRI
    2890.0
    [m]
    DC
    RRI
    2895.0
    [m]
    DC
    RRI
    2900.0
    [m]
    DC
    RRI
    2905.0
    [m]
    DC
    RRI
    2910.0
    [m]
    DC
    RRI
    2915.0
    [m]
    DC
    RRI
    2920.0
    [m]
    DC
    RRI
    2925.0
    [m]
    DC
    RRI
    2930.0
    [m]
    DC
    RRI
    3005.0
    [m]
    DC
    RRI
    3010.0
    [m]
    DC
    RRI
    3015.0
    [m]
    DC
    RRI
    3020.0
    [m]
    DC
    RRI
    3025.0
    [m]
    DC
    RRI
    3030.0
    [m]
    DC
    RRI
    3035.0
    [m]
    DC
    RRI
    3040.0
    [m]
    DC
    RRI
    3045.0
    [m]
    DC
    RRI
    3050.0
    [m]
    DC
    RRI
    3060.0
    [m]
    DC
    RRI
    3065.0
    [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
    3160.0
    [m]
    DC
    RRI
    3165.0
    [m]
    DC
    RRI
    3170.0
    [m]
    DC
    RRI
    3175.0
    [m]
    DC
    RRI
    3180.0
    [m]
    DC
    RRI
    3185.0
    [m]
    DC
    RRI
    3190.0
    [m]
    DC
    RRI
    3195.0
    [m]
    DC
    RRI
    3200.0
    [m]
    DC
    RRI
    3205.0
    [m]
    DC
    RRI
    3210.0
    [m]
    DC
    RRI
    3215.0
    [m]
    DC
    RRI
    3220.0
    [m]
    DC
    RRI
    3225.0
    [m]
    DC
    RRI
    3230.0
    [m]
    DC
    RRI
    3235.0
    [m]
    DC
    RRI
    3240.0
    [m]
    DC
    RRI
    3245.0
    [m]
    DC
    RRI
    3250.0
    [m]
    DC
    RRI
    3260.0
    [m]
    DC
    RRI
    3265.0
    [m]
    DC
    RRI
    3270.0
    [m]
    DC
    RRI
    3275.0
    [m]
    DC
    RRI
    3280.0
    [m]
    DC
    RRI
    3285.0
    [m]
    DC
    RRI
    3290.0
    [m]
    DC
    RRI
    3295.0
    [m]
    DC
    RRI
    3300.0
    [m]
    DC
    RRI
    3305.0
    [m]
    DC
    RRI
    3310.0
    [m]
    DC
    RRI
    3315.0
    [m]
    DC
    RRI
    3320.0
    [m]
    DC
    RRI
    3325.0
    [m]
    DC
    RRI
    3330.0
    [m]
    DC
    RRI
    3335.0
    [m]
    DC
    RRI
    3340.0
    [m]
    DC
    RRI
    3345.0
    [m]
    DC
    RRI