Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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22.11.2024 - 09:09
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6407/6-4

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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.
    6407/6-4
    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
    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.
    6407/6-4
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    8402 - 114 SP. 1420
    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.
    Mobil Exploration 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.
    654-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.
    41
    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,
    31.10.1990
    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.
    13.12.1990
    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.
    13.12.1992
    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.
    09.03.2009
    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.
    APPRAISAL
    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 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.
    219.5
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3126.0
    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).
    3125.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    3.7
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    110
    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.
    64° 37' 36.77'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    7° 40' 51'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7167706.66
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    436926.45
    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.
    1604

  • Wellbore history
    General
    Well 6407/6-4 drilled the Mikkel Structure in the Bremstein Fault Complex, which separates the Trøndelag Platform in the east from the Halten Terrace in the west. The structure is an anticline aligned north-south. The well was planned to reach a total depth of 3150 m. There were no anomalous amplitudes at the planned well location, but there was an indication of shallow gas at 401 to 505 m. The purpose of drilling was to test the possibility of a significant oil leg in the southern part of the Mikkel Structure and to test the communication between the Garn- and Ile Formations in the southern part of the structure.
    Operations and results
    Appraisal well 6407/6-4 was spudded 31 October 1990 by the semi-submersible installation Ross Rig and drilled to TD at 3126 m in Early Jurassic sediments of the Åre Formation. The well was started with a 9 7/8" pilot hole down to 1088 m due to the possibility of shallow gas. No shallow gas was encountered. The well was then opened up and drilled with sea water and viscous pills down to 1085 m, and with KCl/polymer mud from 1085 m to TD. No significant technical problems were encountered in the operations.
    The Garn Formation was penetrated at 2651 m (26 m deeper than prognosis) and was 101 m thick. The reservoir quality of this sandstone was good. The only oil shows recorded during the drilling were in the Garn Formation at 2658 - 2686 m. These were of a poor quality consisting of very dull yellow direct fluorescence, weak light yellow streaming cut fluorescence with a milky cut colour. The shows were patchy with no oil bleeding or hydrocarbon odour being noted.
    Two cores were cut in the well, the first in the Garn Formation of the Fangst Group and the second in the Åre Formation of the Båt Group, both with 100% recovery. The RFT tool was run in the Båt and Fangst Groups. A comparison of pore pressure in the Ile and Tilje Formations show they have slightly higher pore pressure than the Garn Formation. This imply the formations may not be in communication. An RFT fluid sample was obtained from 2661 m in the Garn Formation. It recovered only water.
    The well was permanently abandoned on 13 December 1990 as a dry well with shows.
    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]
    1090.00
    3126.00

  • 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
    2658.0
    2686.0
    [m ]
    2
    3082.0
    3095.1
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    41.1
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 2658-2663m
    Core photo at depth: 2663-2668m
    Core photo at depth: 2668-2673m
    Core photo at depth: 2673-2678m
    Core photo at depth: 2678-2683m
    2658-2663m
    2663-2668m
    2668-2673m
    2673-2678m
    2678-2683m
    Core photo at depth: 2683-2686m
    Core photo at depth: 3082-3087m
    Core photo at depth: 3087-3092m
    Core photo at depth: 3092-3095m
    Core photo at depth:  
    2683-2686m
    3082-3087m
    3087-3092m
    3092-3095m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1117.0
    [m]
    SWC
    RRI
    1200.0
    [m]
    DC
    RRI
    1210.0
    [m]
    DC
    RRI
    1291.0
    [m]
    SWC
    RRI
    1341.0
    [m]
    SWC
    WESTL
    1360.0
    [m]
    DC
    RRI
    1370.0
    [m]
    DC
    RRI
    1378.0
    [m]
    SWC
    RRI
    1420.0
    [m]
    DC
    RRI
    1425.0
    [m]
    SWC
    RRI
    1430.0
    [m]
    DC
    RRI
    1437.0
    [m]
    SWC
    RRI
    1448.0
    [m]
    SWC
    RRI
    1452.0
    [m]
    SWC
    RRI
    1480.0
    [m]
    DC
    RRI
    1490.0
    [m]
    DC
    RRI
    1500.0
    [m]
    DC
    RRI
    1513.0
    [m]
    SWC
    RRI
    1520.0
    [m]
    DC
    RRI
    1528.0
    [m]
    SWC
    RRI
    1540.0
    [m]
    DC
    RRI
    1550.0
    [m]
    DC
    RRI
    1560.0
    [m]
    DC
    RRI
    1570.0
    [m]
    DC
    RRI
    1584.0
    [m]
    SWC
    RRI
    1590.0
    [m]
    DC
    RRI
    1600.0
    [m]
    DC
    RRI
    1611.0
    [m]
    SWC
    RRI
    1620.0
    [m]
    DC
    RRI
    1630.0
    [m]
    DC
    RRI
    1650.0
    [m]
    DC
    RRI
    1660.0
    [m]
    DC
    RRI
    1800.0
    [m]
    DC
    RRI
    1820.0
    [m]
    DC
    RRI
    1830.0
    [m]
    DC
    RRI
    1880.0
    [m]
    DC
    RRI
    1890.0
    [m]
    DC
    RRI
    1910.0
    [m]
    DC
    RRI
    1912.0
    [m]
    SWC
    RRI
    1916.0
    [m]
    SWC
    RRI
    2020.0
    [m]
    DC
    RRI
    2080.0
    [m]
    DC
    RRI
    2100.0
    [m]
    DC
    RRI
    2110.0
    [m]
    DC
    RRI
    2130.0
    [m]
    DC
    RRI
    2140.0
    [m]
    DC
    RRI
    2150.0
    [m]
    DC
    RRI
    2190.0
    [m]
    DC
    RRI
    2200.0
    [m]
    DC
    RRI
    2210.0
    [m]
    DC
    RRI
    2221.0
    [m]
    SWC
    RRI
    2230.0
    [m]
    DC
    RRI
    2236.0
    [m]
    SWC
    RRI
    2252.0
    [m]
    SWC
    RRI
    2260.0
    [m]
    DC
    RRI
    2270.0
    [m]
    DC
    RRI
    2280.0
    [m]
    DC
    RRI
    2290.0
    [m]
    DC
    RRI
    2300.0
    [m]
    DC
    RRI
    2310.0
    [m]
    DC
    RRI
    2320.0
    [m]
    DC
    RRI
    2329.0
    [m]
    SWC
    RRI
    2331.0
    [m]
    SWC
    RRI
    2344.0
    [m]
    SWC
    RRI
    2350.0
    [m]
    DC
    RRI
    2360.0
    [m]
    DC
    RRI
    2370.0
    [m]
    DC
    RRI
    2473.0
    [m]
    SWC
    RRI
    2522.0
    [m]
    SWC
    RRI
    2535.0
    [m]
    SWC
    RRI
    2536.0
    [m]
    SWC
    RRI
    2541.0
    [m]
    DC
    RRI
    2544.0
    [m]
    DC
    RRI
    2547.0
    [m]
    SWC
    RRI
    2553.0
    [m]
    DC
    RRI
    2556.0
    [m]
    DC
    RRI
    2559.0
    [m]
    SWC
    RRI
    2562.0
    [m]
    SWC
    RRI
    2565.0
    [m]
    DC
    RRI
    2568.0
    [m]
    DC
    RRI
    2572.0
    [m]
    SWC
    RRI
    2575.0
    [m]
    SWC
    RRI
    2579.0
    [m]
    SWC
    RRI
    2583.0
    [m]
    DC
    RRI
    2585.0
    [m]
    SWC
    RRI
    2589.0
    [m]
    DC
    RRI
    2592.0
    [m]
    SWC
    RRI
    2595.0
    [m]
    RRI
    RRI
    2598.0
    [m]
    DC
    RRI
    2601.0
    [m]
    SWC
    RRI
    2604.0
    [m]
    DC
    RRI
    2607.0
    [m]
    SWC
    RRI
    2610.0
    [m]
    DC
    RRI
    2613.0
    [m]
    DC
    RRI
    2616.0
    [m]
    SWC
    RRI
    2619.0
    [m]
    DC
    RRI
    2622.0
    [m]
    DC
    RRI
    2625.0
    [m]
    DC
    RRI
    2631.0
    [m]
    SWC
    RRI
    2634.0
    [m]
    DC
    RRI
    2637.0
    [m]
    DC
    RRI
    2640.0
    [m]
    DC
    RRI
    2643.0
    [m]
    SWC
    RRI
    2650.0
    [m]
    SWC
    RRI
    2652.0
    [m]
    DC
    RRI
    2658.0
    [m]
    C
    RRI
    2663.0
    [m]
    C
    RRI
    2677.0
    [m]
    C
    RRI
    2691.0
    [m]
    DC
    RRI
    2712.0
    [m]
    DC
    RRI
    2729.0
    [m]
    SWC
    RRI
    2751.0
    [m]
    DC
    RRI
    2769.0
    [m]
    DC
    RRI
    2781.0
    [m]
    DC
    RRI
    2790.0
    [m]
    DC
    RRI
    2800.0
    [m]
    SWC
    RRI
    2805.0
    [m]
    SWC
    RRI
    2820.0
    [m]
    DC
    RRI
    2829.0
    [m]
    DC
    RRI
    2841.0
    [m]
    DC
    RRI
    2850.0
    [m]
    SWC
    RRI
    2856.0
    [m]
    SWC
    RRI
    2871.0
    [m]
    DC
    RRI
    2880.0
    [m]
    DC
    RRI
    2889.0
    [m]
    DC
    RRI
    2901.0
    [m]
    DC
    RRI
    2905.0
    [m]
    SWC
    RRI
    2915.0
    [m]
    SWC
    RRI
    2925.0
    [m]
    DC
    RRI
    2933.0
    [m]
    SWC
    RRI
    2942.0
    [m]
    SWC
    RRI
    2949.0
    [m]
    DC
    RRI
    2961.0
    [m]
    DC
    RRI
    2972.0
    [m]
    SWC
    RRI
    2982.0
    [m]
    SWC
    RRI
    2993.0
    [m]
    SWC
    RRI
    2997.0
    [m]
    SWC
    RRI
    3009.0
    [m]
    DC
    RRI
    3021.0
    [m]
    DC
    RRI
    3030.0
    [m]
    DC
    RRI
    3038.0
    [m]
    SWC
    RRI
    3047.0
    [m]
    SWC
    RRI
    3056.0
    [m]
    SWC
    RRI
    3069.0
    [m]
    DC
    RRI
    3082.0
    [m]
    C
    RRI
    3099.0
    [m]
    DC
    RRI
    3105.0
    [m]
    SWC
    RRI
    3114.0
    [m]
    DC
    RRI
    3126.0
    [m]
    DC
    RRI

  • Oil samples at the Norwegian Offshore Directorate
    Oil samples at the Norwegian Offshore Directorate
    Test type
    Bottle number
    Top depth
    MD [m]
    Bottom depth
    MD [m]
    Fluid type
    Test time
    Samples available
    DST
    0.00
    0.00
    YES

  • Lithostratigraphy

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.13
    pdf
    7.68
    pdf
    0.44
    pdf
    0.62

  • 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
    28.72

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL
    168
    2496
    CST
    1090
    2490
    CST
    2511
    3105
    DIL LSS GR
    1079
    3130
    LDL CAL GR AMS
    1079
    3130
    MWD
    243
    3082
    RFT
    2661
    2965
    SHDT
    2496
    3129
    VSP
    400
    3120

  • 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
    353.0
    36
    357.0
    0.00
    LOT
    INTERM.
    20
    1079.0
    26
    1085.0
    1.73
    LOT
    INTERM.
    13 3/8
    2492.0
    17 1/2
    2500.0
    1.91
    LOT
    INTERM.
    9 5/8
    3126.0
    12 1/4
    3126.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    279
    1.02
    15.0
    20.0
    WATER BASED
    05.11.1990
    352
    1.02
    15.0
    20.0
    WATER BASED
    06.11.1990
    356
    1.02
    15.0
    20.0
    WATER BASED
    05.11.1990
    507
    1.01
    15.0
    20.0
    WATER BASED
    01.11.1990
    596
    1.02
    67.0
    13.0
    WATER BASED
    07.11.1990
    870
    1.02
    67.0
    13.0
    WATER BASED
    08.11.1990
    1078
    1.02
    67.0
    13.0
    WATER BASED
    09.11.1990
    1082
    1.02
    15.0
    20.0
    WATER BASED
    02.11.1990
    1085
    1.06
    14.0
    100.0
    WATER BASED
    12.11.1990
    1088
    1.02
    15.0
    20.0
    WATER BASED
    05.11.1990
    1426
    1.37
    24.0
    20.0
    WATER BASED
    13.11.1990
    1770
    1.55
    28.0
    30.0
    WATER BASED
    15.11.1990
    2042
    1.60
    24.0
    32.0
    WATER BASED
    15.11.1990
    2082
    1.62
    17.0
    15.0
    WATER BASED
    19.11.1990
    2352
    1.62
    17.0
    20.0
    WATER BASED
    19.11.1990
    2439
    1.62
    21.0
    17.0
    WATER BASED
    22.11.1990
    2500
    1.62
    18.0
    16.0
    WATER BASED
    22.11.1990
    2500
    1.62
    18.0
    16.0
    WATER BASED
    27.11.1990
    2514
    1.62
    18.0
    16.0
    WATER BASED
    27.11.1990
    2658
    1.20
    18.0
    16.0
    WATER BASED
    28.11.1990
    2686
    1.20
    18.0
    16.0
    WATER BASED
    29.11.1990
    2769
    1.20
    18.0
    16.0
    WATER BASED
    30.11.1990
    2965
    1.20
    18.0
    16.0
    WATER BASED
    03.12.1990
    3082
    1.20
    18.0
    16.0
    WATER BASED
    03.12.1990
    3095
    1.20
    18.0
    16.0
    WATER BASED
    04.12.1990
    3126
    1.20
    18.0
    16.0
    WATER BASED
    05.12.1990
    3126
    1.20
    18.0
    16.0
    WATER BASED
    14.12.1990
    3126
    1.20
    18.0
    16.0
    WATER BASED
    11.12.1990
    3126
    1.20
    18.0
    16.0
    WATER BASED
    12.12.1990
    3126
    1.20
    18.0
    16.0
    WATER BASED
    14.12.1990

  • 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
    0.27