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

6507/7-10

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.
    6507/7-10
    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
    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.
    6507/7-10
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    ST 9102-3D - INLINE1152 & CROSSLINE 1390
    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.
    771-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.
    32
    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,
    28.09.1993
    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.
    29.10.1993
    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.
    29.10.1995
    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.
    13.12.2005
    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.
    SHOWS
    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.
    23.5
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    394.5
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3309.0
    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).
    3306.0
    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.
    107
    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 TRIASSIC
    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.
    GREY BEDS (INFORMAL)
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    65° 23' 26.83'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    7° 19' 56.32'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7253215.71
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    422511.29
    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.
    2182

  • Wellbore history
    General
    Well 6507/7-10 was the third and last of the commitment wells to be drilled on PL 095. The well was located 200 km off the mid-Norwegian coast and approximately 7.5 km north of the Heidrun Field. The structure drilled was a graben down faulted from the Heidrun Field. The primary objective of well 6507/7-10 was to test the presence of commercial hydrocarbons in Middle Jurassic Fangst Group Sandstones. The Early Jurassic Tilje and Åre Formations were secondary objectives. Both Tilje and Are formations would be encountered below the known hydrocarbon contacts observed within the Heidrun and Heidrun Nord Fields, and the potential for hydrocarbons in these formations would depend on fault seal for closure. TD was planned in Triassic strata or 4000 m.
    Operations and results
    Wildcat well was spudded with the semi-submersible installation Arcade Frontier on 28 September 1993 and drilled to TD at 3309.5 m in the Triassic Grey Beds. The well was drilled with spud mud down to 1150 m and with KCl/polymer mud from 1150 m to TD.
    A 56 m thick Fangst section (Garn, Not and Ile) was penetrated with top Fangst at 2507 m, 61 m below prognosed top. The BÅt group consisted of 42.5 m Ror Formation, 155 m Tilje Formation and 412 m of Åre Formation. Good sands with average log porosities from 24% to 29% were found in the Garn, Ile, Tilje, and Åre Formations. Unexpected Late Jurassic (Spekk and Melke) sections with thin sand zones with traces of hydrocarbons were penetrated. Apart from these shows all sands in the well were found 100% water wet. Geochemical analyses of an extract from 2477 m in the thin Melke Formation sand indicated that the hydrocarbons here were generated in a more mature source rock (%Ro = 0.75 - 0.80) than the in-situ shales at this level (Ro = 0.6%).
    Three cores were cut with 85%, 80% and 100% recovery respectively. The two first cores were cut in the thin Late Jurassic sand zones (2448.5-2454.5 m and 2476.5-2481.0 m). The third core was cut in the Middle Jurassic Fangst Group (2525.0-2551.0 m). Weak to no shows were reported from all cores. A total of 20 FMT pressure tests were successfully obtained, the first pressure point was recorded at 2511 m in the Fangst Group and the last at 3280 m in the Triassic. A fluid sample was planned in the Late Jurassic to test out the shows encountered in the thin sand zones. It was however excluded since the density log indicated that the horizon was too tight to give any successful fluid sample. Otherwise no sample was considered and none were taken.
    The well was permanently abandoned on 29 October as a well with shows.
    Testing
    No drill stem test was performed in the well.

  • 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]
    1170.00
    3308.00

  • 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
    2448.0
    2453.1
    [m ]
    2
    2476.5
    2480.1
    [m ]
    3
    2525.0
    2551.0
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    34.7
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 2448-2453m
    Core photo at depth: 2453-2453m
    Core photo at depth: 2476-2480m
    Core photo at depth: 2525-2530m
    Core photo at depth: 2530-2535m
    2448-2453m
    2453-2453m
    2476-2480m
    2525-2530m
    2530-2535m
    Core photo at depth: 2535-2540m
    Core photo at depth: 2540-2545m
    Core photo at depth: 2545-2550m
    Core photo at depth: 2550-2551m
    Core photo at depth:  
    2535-2540m
    2540-2545m
    2545-2550m
    2550-2551m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1170.0
    [m]
    DC
    RRI
    1200.0
    [m]
    DC
    RRI
    1230.0
    [m]
    DC
    RRI
    1260.0
    [m]
    DC
    RRI
    1290.0
    [m]
    DC
    RRI
    1330.0
    [m]
    DC
    RRI
    1360.0
    [m]
    DC
    RRI
    1390.0
    [m]
    DC
    RRI
    1420.0
    [m]
    DC
    RRI
    1450.0
    [m]
    DC
    RRI
    1480.0
    [m]
    DC
    RRI
    1520.0
    [m]
    DC
    RRI
    1550.0
    [m]
    DC
    RRI
    1580.0
    [m]
    DC
    RRI
    1610.0
    [m]
    DC
    RRI
    1640.0
    [m]
    DC
    RRI
    1670.0
    [m]
    DC
    RRI
    1700.0
    [m]
    DC
    RRI
    1730.0
    [m]
    DC
    RRI
    1760.0
    [m]
    DC
    RRI
    1790.0
    [m]
    DC
    RRI
    1820.0
    [m]
    DC
    RRI
    1850.0
    [m]
    DC
    RRI
    1880.0
    [m]
    DC
    RRI
    1910.0
    [m]
    DC
    RRI
    1940.0
    [m]
    DC
    RRI
    1970.0
    [m]
    DC
    RRI
    1990.0
    [m]
    DC
    RRI
    2019.5
    [m]
    SWC
    RRI
    2052.5
    [m]
    SWC
    RRI
    2097.0
    [m]
    SWC
    RRI
    2103.0
    [m]
    SWC
    RRI
    2113.0
    [m]
    SWC
    RRI
    2126.0
    [m]
    SWC
    RRI
    2154.5
    [m]
    SWC
    RRI
    2168.0
    [m]
    SWC
    RRI
    2195.0
    [m]
    SWC
    RRI
    2222.0
    [m]
    SWC
    RRI
    2268.0
    [m]
    SWC
    RRI
    2288.5
    [m]
    SWC
    RRI
    2303.0
    [m]
    SWC
    RRI
    2319.0
    [m]
    SWC
    RRI
    2335.0
    [m]
    SWC
    RRI
    2342.5
    [m]
    SWC
    RRI
    2362.5
    [m]
    SWC
    RRI
    2373.5
    [m]
    SWC
    RRI
    2379.0
    [m]
    SWC
    RRI
    2384.0
    [m]
    SWC
    RRI
    2390.5
    [m]
    SWC
    RRI
    2420.0
    [m]
    SWC
    RRI
    2438.0
    [m]
    DC
    RRI
    2448.0
    [m]
    C
    RRI
    2452.0
    [m]
    C
    RRI
    2461.0
    [m]
    SWC
    RRI
    2468.0
    [m]
    SWC
    RRI
    2470.0
    [m]
    SWC
    RRI
    2472.0
    [m]
    SWC
    RRI
    2474.0
    [m]
    SWC
    RRI
    2476.5
    [m]
    C
    RRI
    2477.0
    [m]
    C
    RRI
    2477.2
    [m]
    C
    RRI
    2480.0
    [m]
    DC
    RRI
    2480.0
    [m]
    C
    RRI
    2487.0
    [m]
    SWC
    RRI
    2502.0
    [m]
    SWC
    RRI
    2505.0
    [m]
    SWC
    RRI
    2510.0
    [m]
    SWC
    RRI
    2515.0
    [m]
    SWC
    RRI
    2525.1
    [m]
    C
    RRI
    2534.7
    [m]
    C
    RRI
    2546.7
    [m]
    C
    RRI
    2550.5
    [m]
    C
    RRI
    2557.0
    [m]
    SWC
    RRI
    2558.0
    [m]
    SWC
    RRI
    2560.5
    [m]
    SWC
    RRI
    2562.0
    [m]
    SWC
    RRI
    2565.0
    [m]
    SWC
    RRI
    2580.0
    [m]
    SWC
    RRI
    2590.0
    [m]
    SWC
    RRI
    2595.0
    [m]
    SWC
    RRI
    2599.0
    [m]
    SWC
    RRI
    2601.0
    [m]
    SWC
    RRI
    2618.0
    [m]
    DC
    RRI
    2632.0
    [m]
    SWC
    RRI
    2648.0
    [m]
    DC
    RRI
    2660.0
    [m]
    DC
    RRI
    2672.0
    [m]
    DC
    RRI
    2681.0
    [m]
    DC
    RRI
    2696.0
    [m]
    DC
    RRI
    2708.0
    [m]
    DC
    RRI
    2720.0
    [m]
    DC
    RRI
    2730.0
    [m]
    DC
    RRI
    2738.0
    [m]
    SWC
    RRI
    2747.0
    [m]
    DC
    RRI
    2759.0
    [m]
    DC
    RRI
    2771.0
    [m]
    DC
    RRI
    2783.0
    [m]
    DC
    RRI
    2795.0
    [m]
    DC
    RRI
    2810.0
    [m]
    DC
    RRI
    2822.0
    [m]
    DC
    RRI
    2831.0
    [m]
    DC
    RRI
    2843.0
    [m]
    DC
    RRI
    2858.0
    [m]
    DC
    RRI
    2870.0
    [m]
    DC
    RRI
    2882.0
    [m]
    DC
    RRI
    2893.0
    [m]
    SWC
    RRI
    2894.0
    [m]
    DC
    RRI
    2906.0
    [m]
    DC
    RRI
    2918.0
    [m]
    DC
    RRI
    2930.0
    [m]
    DC
    RRI
    2942.0
    [m]
    DC
    RRI
    2954.0
    [m]
    DC
    RRI
    2966.0
    [m]
    DC
    RRI
    2978.0
    [m]
    DC
    RRI
    2993.0
    [m]
    DC
    RRI
    3005.0
    [m]
    DC
    RRI
    3014.0
    [m]
    DC
    RRI
    3026.0
    [m]
    DC
    RRI
    3044.0
    [m]
    DC
    RRI
    3056.0
    [m]
    SWC
    RRI
    3068.0
    [m]
    DC
    RRI
    3080.0
    [m]
    DC
    RRI
    3092.0
    [m]
    DC
    RRI
    3110.0
    [m]
    DC
    RRI
    3122.0
    [m]
    DC
    RRI
    3134.0
    [m]
    DC
    RRI
    3146.0
    [m]
    DC
    RRI
    3158.0
    [m]
    DC
    RRI
    3165.0
    [m]
    SWC
    RRI
    3177.0
    [m]
    SWC
    RRI
    3193.0
    [m]
    SWC
    RRI
    3212.5
    [m]
    SWC
    RRI
    3223.0
    [m]
    SWC
    RRI
    3237.0
    [m]
    SWC
    RRI
    3257.0
    [m]
    DC
    RRI
    3272.0
    [m]
    DC
    RRI
    3284.0
    [m]
    DC
    RRI
    3299.0
    [m]
    DC
    RRI

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.33

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    6.89

  • 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
    79.23

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    DPIL DAC ZDL CN SL
    2403
    3305
    FMT GR
    2471
    3280
    GR DIFL ACL
    1150
    2410
    HDIP GR
    2403
    3291
    MWD CDR - GR RES DIR
    500
    2416
    MWD CDR - GR RES DIR
    2400
    3310
    SWC GR
    1972
    2390
    SWC GR
    2420
    3287
    VSP
    1290
    3280
    ZDL GR
    2403
    3305

  • 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
    518.0
    36
    519.0
    0.00
    LOT
    INTERM.
    13 3/8
    1150.0
    17 1/2
    1161.0
    1.60
    LOT
    INTERM.
    9 5/8
    2407.0
    12 1/4
    2416.0
    1.75
    LOT
    OPEN HOLE
    3309.5
    8 1/2
    3309.5
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    521
    1.07
    120.0
    Hi Vis mud
    1160
    1.20
    55.0
    Hi Vis mud
    1700
    1.42
    52.0
    waterbased
    2290
    1.42
    53.0
    waterbased
    2416
    1.46
    57.0
    waterbased
    3309
    1.20
    159.0
    waterbased

  • 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