Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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15.07.2024 - 01:28
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6507/5-4

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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.
    6507/5-4
    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
    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.
    6507/5-4
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    xline 1865 & inline 1157
    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.
    BP Amoco Norge 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.
    995-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,
    10.02.2001
    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.
    15.04.2001
    Plugged date
    Date when plugging operations was finished, as reported by the operator to the Norwegian Offshore Directorate through DDRS (Daily Drilling Reporting System).
    15.04.2001
    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.
    15.04.2003
    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.
    OIL/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.
    EARLY 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.
    LANGE 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.
    GARN FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    25.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    421.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3812.0
    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).
    3811.2
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    6.7
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    124
    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° 41' 44.78'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    7° 34' 13.62'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7286930.97
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    434346.79
    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.
    4209
  • Wellbore history

    General
    Exploration wells 6507/6-1 and 6507/6-2 were drilled by Saga in the period 1986 to 1991. Both were plugged and abandoned as dry with shows. The Amoco operated exploration well 6507/5-1 well was completed in 1998 and was suspended as an oil and gas discovery in the Jurassic and Cretaceous. The discovery was named Skarv while the Cretaceous part of it has informally been named Gråsel. In 1999, well 6507/5-2 was drilled by BP Amoco to appraise Skarv. The well was plugged and abandoned as a gas well. The Snadd structure was explored by the 6507/5-3 well in June 2000 and plugged and abandoned as a gas discovery.
    Well 6507/5-4 was drilled on the southern C-segment of the Skarv structure. The main reservoir target was sandstone in the Early - Middle Jurassic Garn, Ile and Tilje Formations. In the discovery case the objective was to gather the data required to allow confident oil reserves estimates. High-risk secondary targets were the Cretaceous Lysing and Lange Formations.
    Operations and results
    Wildcat well 6507/5-4 was spudded with the semi-submersible installation Stena Dee on 10 February 2001 and drilled to TD at 3812 m (3820 m loggers depth) in the Early Jurassic sediments of the Åre Formation. The well was drilled with seawater and hi-vis sweeps down to 522 m, with KCl/glycol mud from 522 m to 1468 m, and with KCl mud from 1468 m to TD.
    Well 6507/5-4 successfully completed a logging program across Cretaceous secondary targets in the 12.25" hole, and a logging and coring programme of the primary Jurassic targets in 8.5" hole. Oil shows of variable strength were recorded from 3060 in the Lange Formation and down to TD. Oil and condensate were discovered in poor quality Early Cretaceous sands. The thin Lysing Formation was tight without shows. Oil and gas were discovered from 3513 m, top of the primary Garn reservoir target, while Ile and Tilje were water-wet. A gas/oil contact was indicated at 3542 m based on logs and cores, but no OWC was seen.
    Four conventional cores were cut in the Garn, Not, Ile, Ror, and Tilje Formations in the interval 3512 m to 3724 m. The core-log shift was ca + 7 m for all four cores. MDT fluid samples were taken in the Lange Formation as well as in the Fangst Group. Organic geochemical analyses of these indicated a similar source rock, but with a somewhat higher maturity in the Lange Formation petroleum.
    The well bore was plugged back to 1450 m on 15 April 2001 as an oil/gas appraisal of the Skarv Discovery. Since no OWC had been found a sidetrack, 6507/5-4 A, was decided to appraise the Garn down-dip oil leg.
    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]
    1470.00
    3812.00
  • 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
    3512.5
    3534.5
    [m ]
    2
    3535.0
    3594.5
    [m ]
    3
    3594.0
    3679.0
    [m ]
    4
    3678.0
    3722.5
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    211.0
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES
  • Palynological slides at the Norwegian Offshore Directorate

    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1470.0
    [m]
    DC
    RESLAB
    1500.0
    [m]
    DC
    RESLAB
    1530.0
    [m]
    DC
    RESLAB
    1560.0
    [m]
    DC
    RESLAB
    1590.0
    [m]
    DC
    RESLAB
    1620.0
    [m]
    DC
    RESLAB
    1650.0
    [m]
    DC
    RESLAB
    1680.0
    [m]
    DC
    RESLAB
    1710.0
    [m]
    DC
    RESLAB
    1740.0
    [m]
    DC
    RESLAB
    1770.0
    [m]
    DC
    RESLAB
    1800.0
    [m]
    DC
    RESLAB
    1830.0
    [m]
    DC
    RESLAB
    1860.0
    [m]
    DC
    RESLAB
    1890.0
    [m]
    DC
    RESLAB
    1920.0
    [m]
    DC
    RESLAB
    1950.0
    [m]
    DC
    RESLAB
    1980.0
    [m]
    DC
    RESLAB
    2000.0
    [m]
    DC
    RESLAB
    2030.0
    [m]
    DC
    RESLAB
    2050.0
    [m]
    DC
    RESLAB
    2080.0
    [m]
    DC
    RESLAB
    2100.0
    [m]
    DC
    RESLAB
    2130.0
    [m]
    DC
    RESLAB
    2150.0
    [m]
    DC
    RESLAB
    2180.0
    [m]
    DC
    RESLAB
    2200.0
    [m]
    DC
    RESLAB
    2230.0
    [m]
    DC
    RESLAB
    2250.0
    [m]
    DC
    RESLAB
    2280.0
    [m]
    DC
    RESLAB
    2300.0
    [m]
    DC
    RESLAB
    2320.0
    [m]
    DC
    RESLAB
    2350.0
    [m]
    DC
    RESLAB
    2380.0
    [m]
    DC
    RESLAB
    2400.0
    [m]
    DC
    RESLAB
    2430.0
    [m]
    DC
    RESLAB
    2450.0
    [m]
    DC
    RESLAB
    2480.0
    [m]
    DC
    RESLAB
    2500.0
    [m]
    DC
    RESLAB
    2530.0
    [m]
    DC
    RESLAB
    2550.0
    [m]
    DC
    RESLAB
    2580.0
    [m]
    DC
    RESLAB
    2600.0
    [m]
    DC
    RESLAB
    2630.0
    [m]
    DC
    RESLAB
    2650.0
    [m]
    DC
    RESLAB
    2670.0
    [m]
    DC
    RESLAB
    2701.0
    [m]
    DC
    RESLAB
    2725.0
    [m]
    DC
    RESLAB
    2749.0
    [m]
    DC
    RESLAB
    2776.0
    [m]
    DC
    RESLAB
    2785.0
    [m]
    DC
    RESLAB
    2800.0
    [m]
    DC
    RESLAB
    2815.0
    [m]
    DC
    RESLAB
    2830.0
    [m]
    DC
    RESLAB
    2842.0
    [m]
    DC
    RESLAB
    2860.0
    [m]
    DC
    RESLAB
    2875.0
    [m]
    DC
    RESLAB
    2890.0
    [m]
    DC
    RESLAB
    2905.0
    [m]
    DC
    RESLAB
    2920.0
    [m]
    DC
    RESLAB
    2935.0
    [m]
    DC
    RESLAB
    2950.0
    [m]
    DC
    RESLAB
    2964.0
    [m]
    DC
    RESLAB
    2980.0
    [m]
    DC
    RESLAB
    2995.0
    [m]
    DC
    RESLAB
    3010.0
    [m]
    DC
    RESLAB
    3025.0
    [m]
    DC
    RESLAB
    3028.9
    [m]
    SWC
    RESLAB
    3046.8
    [m]
    SWC
    RESLAB
    3070.0
    [m]
    DC
    RESLAB
    3089.9
    [m]
    SWC
    RESLAB
    3101.7
    [m]
    SWC
    RESLAB
    3111.0
    [m]
    SWC
    RESLAB
    3129.9
    [m]
    SWC
    RESLAB
    3145.0
    [m]
    DC
    RESLAB
    3160.0
    [m]
    DC
    RESLAB
    3190.0
    [m]
    DC
    RESLAB
    3205.0
    [m]
    DC
    RESLAB
    3225.1
    [m]
    SWC
    RESLAB
    3235.0
    [m]
    DC
    RESLAB
    3244.4
    [m]
    SWC
    RESLAB
    3265.0
    [m]
    DC
    RESLAB
    3331.0
    [m]
    DC
    RESLAB
    3346.0
    [m]
    DC
    RESLAB
    3727.0
    [m]
    DC
    RESLAB
    3739.0
    [m]
    DC
    RESLAB
    3748.0
    [m]
    DC
    RESLAB
    3754.0
    [m]
    DC
    RESLAB
    3766.0
    [m]
    DC
    RESLAB
    3772.0
    [m]
    DC
    RESLAB
    3781.0
    [m]
    DC
    RESLAB
    3796.0
    [m]
    DC
    RESLAB
    3802.0
    [m]
    DC
    RESLAB
    3812.0
    [m]
    DC
    RESLAB
  • Lithostratigraphy

  • Geochemical information

    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    4.70
    pdf
    4.25
  • 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
    1.93
    .PDF
    0.71
  • Logs

    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    HRLA DSI GR SP EMS GPIT
    420
    3475
    HRLA DSI GR SP EMS GPIT
    3300
    3820
    IPLT GR
    1460
    3473
    IPLT GR
    3498
    3820
    LWD - CWR GR
    519
    2203
    LWD - MPR GR
    1700
    3512
    MDT GR
    2788
    3245
    MDT GR
    3514
    3621
    MDT GR
    3514
    3575
    MDT GR
    3562
    3811
    MDT GR
    3566
    3582
    MSCT GR
    3028
    3245
    VSP
    445
    3460
    VSP GR
    3350
    3810
    VSP GR
    3765
    3810
  • 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
    519.0
    36
    522.0
    0.00
    LOT
    SURF.COND.
    20
    1461.0
    26
    1466.0
    1.62
    LOT
    INTERM.
    9 5/8
    3494.0
    12 1/4
    3501.0
    2.01
    LOT
    OPEN HOLE
    3820.0
    8 1/2
    3820.0
    0.00
    LOT
  • Drilling mud

    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    519
    0.00
    1.0
    SPUD MUD
    1051
    0.00
    1.0
    SPUD MUD
    1466
    0.00
    1.0
    SPUD MUD
    1623
    0.00
    15.0
    KCL
    1635
    1.39
    24.0
    KCL
    2143
    0.00
    20.0
    KCL
    2203
    0.00
    20.0
    KCL
    2648
    1.61
    27.0
    KCL
    2850
    1.61
    25.0
    KCL
    2999
    1.61
    30.0
    KCL
    3271
    1.61
    20.0
    KCL
    3488
    1.61
    27.0
    KCL
    3500
    1.62
    36.0
    KCL
    3535
    1.30
    17.0
    KCL
    3709
    1.63
    25.0
    KCL
    3812
    1.34
    20.0
    KCL
    3883
    1.25
    0.2
    WATER/BRINE
    3883
    1.28
    12.0
    KCL
  • 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