Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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sodir.no          Norsk
25.11.2024 - 01:30
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6407/8-7

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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.
    6407/8-7
    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
    Well name
    Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    6407/8-7
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    ST10021Z14 : inline 1617 & crossline 1871
    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.
    Statoil Petroleum 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.
    1576-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.
    16
    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,
    27.04.2015
    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.
    12.05.2015
    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.
    12.05.2017
    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.
    12.05.2017
    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.
    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.
    40.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    259.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3030.0
    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).
    3030.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    0.9
    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° 23' 4.27'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    7° 33' 42.94'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7140825.54
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    430630.00
    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.
    7684

  • Wellbore history
    General
    Well 6407/8-7 and its sidetrack 6407/8-7 A were drilled to test the Bister prospect about four kilometres north of the Hyme field in the southern part of the Norwegian Sea and 140 kilometres north of Kristiansund. The objective of the main wellbore 6407/8-7 was to test the hydrocarbon potential in the Ile Formation. The secondary objective was to test the potential in the Tilje and Åre Formations.
    Operations and results
    Wildcat well 6407/8-7 was spudded with the semi-submersible installation Transocean Spitsbergen on 12 May 2015 and drilled to TD at 3030 m in the Early Jurassic Åre Formation. No significant problem was encountered in the operations. The well was drilled with seawater and polymer based hi-vis sweeps down to 1055 m, and with EMS-4400 oil based mud from 1055 m to TD. Due to corals in the area, environmental restrictions allowed no solids in the mud.
    The well encountered about 95 m of the Ile formation, of which 70 m were sandstone with good reservoir properties. The Tilje and Åre formations were also encountered, in thicknesses of 200 m and 170 m respectively, of which 160 m and 75 m respectively are sandstone with good reservoir quality. The well is dry. Some shows were observed on cuttings in both the main well and the sidetrack. However, when using OBM most HC's will be washed out and/or masked by the oil base in the mud. Preliminary post well analysis confirms that the shows observed on cuttings were from the OBM and not formation.
    No cores were cut. No fluid sample was taken. Formation pressure were measured with the stethoscope tool during wipertrip, post drilling. The valid pressures plot on two water gradients: one through Ile and Tofte, and a second with ca 2 bar higher pressure through the Tilje Formation.
    The well was plugged back for sidetracking on 12 May 2015. It is classified as a dry well.
    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]
    1060.00
    3030.00

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1300.0
    [m]
    DC
    APT
    1320.0
    [m]
    DC
    APT
    1360.0
    [m]
    DC
    APT
    1380.0
    [m]
    DC
    APT
    1420.0
    [m]
    DC
    APT
    1440.0
    [m]
    DC
    APT
    1460.0
    [m]
    DC
    APT
    1480.0
    [m]
    DC
    APT
    1500.0
    [m]
    DC
    APT
    1520.0
    [m]
    DC
    APT
    1540.0
    [m]
    DC
    APT
    1560.0
    [m]
    DC
    APT
    1580.0
    [m]
    DC
    APT
    1600.0
    [m]
    DC
    APT
    1620.0
    [m]
    DC
    APT
    1640.0
    [m]
    DC
    APT
    1700.0
    [m]
    DC
    APT
    1720.0
    [m]
    DC
    APT
    1740.0
    [m]
    DC
    APT
    1760.0
    [m]
    DC
    APT
    1780.0
    [m]
    DC
    APT
    1800.0
    [m]
    DC
    APT
    1820.0
    [m]
    DC
    APT
    1840.0
    [m]
    DC
    APT
    1860.0
    [m]
    DC
    APT
    1880.0
    [m]
    DC
    APT
    1900.0
    [m]
    DC
    APT
    1920.0
    [m]
    DC
    APT
    1940.0
    [m]
    DC
    APT
    1960.0
    [m]
    DC
    APT
    1980.0
    [m]
    DC
    APT
    2000.0
    [m]
    DC
    APT
    2020.0
    [m]
    DC
    APT
    2040.0
    [m]
    DC
    APT
    2060.0
    [m]
    DC
    APT
    2080.0
    [m]
    DC
    APT
    2100.0
    [m]
    DC
    APT
    2120.0
    [m]
    DC
    APT
    2140.0
    [m]
    DC
    APT
    2160.0
    [m]
    DC
    APT
    2180.0
    [m]
    DC
    APT
    2200.0
    [m]
    DC
    APT
    2220.0
    [m]
    DC
    APT
    2240.0
    [m]
    DC
    APT
    2260.0
    [m]
    DC
    APT
    2280.0
    [m]
    DC
    APT
    2300.0
    [m]
    DC
    APT
    2320.0
    [m]
    DC
    APT
    2340.0
    [m]
    DC
    APT
    2360.0
    [m]
    DC
    APT
    2380.0
    [m]
    DC
    APT
    2386.0
    [m]
    DC
    APT
    2392.0
    [m]
    DC
    APT
    2398.0
    [m]
    DC
    APT
    2407.0
    [m]
    DC
    APT
    2413.0
    [m]
    DC
    APT
    2419.0
    [m]
    DC
    APT
    2425.0
    [m]
    DC
    APT
    2434.0
    [m]
    DC
    APT
    2440.0
    [m]
    DC
    APT
    2446.0
    [m]
    DC
    APT
    2452.0
    [m]
    DC
    APT
    2455.0
    [m]
    DC
    APT
    2458.0
    [m]
    DC
    APT
    2461.0
    [m]
    DC
    APT
    2464.0
    [m]
    DC
    APT
    2467.0
    [m]
    DC
    APT
    2470.0
    [m]
    DC
    APT
    2473.0
    [m]
    DC
    APT
    2476.0
    [m]
    DC
    APT
    2479.0
    [m]
    DC
    APT
    2482.0
    [m]
    DC
    APT
    2485.0
    [m]
    DC
    APT
    2488.0
    [m]
    DC
    APT
    2491.0
    [m]
    DC
    APT
    2494.0
    [m]
    DC
    APT
    2497.0
    [m]
    DC
    APT
    2500.0
    [m]
    DC
    APT
    2503.0
    [m]
    DC
    APT
    2506.0
    [m]
    DC
    APT
    2509.0
    [m]
    DC
    APT
    2512.0
    [m]
    DC
    APT
    2515.0
    [m]
    DC
    APT
    2518.0
    [m]
    DC
    APT
    2521.0
    [m]
    DC
    APT
    2524.0
    [m]
    DC
    APT
    2527.0
    [m]
    DC
    APT
    2530.0
    [m]
    DC
    APT
    2533.0
    [m]
    DC
    APT
    2536.0
    [m]
    DC
    APT
    2539.0
    [m]
    DC
    APT
    2542.0
    [m]
    DC
    APT
    2545.0
    [m]
    DC
    APT
    2548.0
    [m]
    DC
    APT
    2551.0
    [m]
    DC
    APT
    2554.0
    [m]
    DC
    APT
    2557.0
    [m]
    DC
    APT
    2560.0
    [m]
    DC
    APT
    2563.0
    [m]
    DC
    APT
    2566.0
    [m]
    DC
    APT
    2569.0
    [m]
    DC
    APT
    2572.0
    [m]
    DC
    APT
    2575.0
    [m]
    DC
    APT
    2578.0
    [m]
    DC
    APT
    2581.0
    [m]
    DC
    APT
    2584.0
    [m]
    DC
    APT
    2587.0
    [m]
    DC
    APT
    2590.0
    [m]
    DC
    APT
    2593.0
    [m]
    DC
    APT
    2596.0
    [m]
    DC
    APT
    2599.0
    [m]
    DC
    APT
    2602.0
    [m]
    DC
    APT
    2605.0
    [m]
    DC
    APT
    2608.0
    [m]
    DC
    APT
    2611.0
    [m]
    DC
    APT
    2614.0
    [m]
    DC
    APT
    2617.0
    [m]
    DC
    APT
    2620.0
    [m]
    DC
    APT
    2623.0
    [m]
    DC
    APT
    2626.0
    [m]
    DC
    APT
    2629.0
    [m]
    DC
    APT
    2632.0
    [m]
    DC
    APT
    2635.0
    [m]
    DC
    APT
    2638.0
    [m]
    DC
    APT
    2641.0
    [m]
    DC
    APT
    2644.0
    [m]
    DC
    APT
    2647.0
    [m]
    DC
    APT
    2650.0
    [m]
    DC
    APT
    2653.0
    [m]
    DC
    APT
    2656.0
    [m]
    DC
    APT
    2659.0
    [m]
    DC
    APT
    2662.0
    [m]
    DC
    APT
    2665.0
    [m]
    DC
    APT
    2668.0
    [m]
    DC
    APT
    2671.0
    [m]
    DC
    APT
    2674.0
    [m]
    DC
    APT
    2677.0
    [m]
    DC
    APT
    2680.0
    [m]
    DC
    APT
    2683.0
    [m]
    DC
    APT
    2686.0
    [m]
    DC
    APT
    2689.0
    [m]
    DC
    APT
    2692.0
    [m]
    DC
    APT
    2695.0
    [m]
    DC
    APT
    2698.0
    [m]
    DC
    APT
    2701.0
    [m]
    DC
    APT
    2704.0
    [m]
    DC
    APT
    2707.0
    [m]
    DC
    APT
    2710.0
    [m]
    DC
    APT
    2713.0
    [m]
    DC
    APT
    2716.0
    [m]
    DC
    APT
    2719.0
    [m]
    DC
    APT
    2722.0
    [m]
    DC
    APT
    2722.0
    [m]
    DC
    APT
    2728.0
    [m]
    DC
    APT
    2731.0
    [m]
    DC
    APT
    2734.0
    [m]
    DC
    APT
    2737.0
    [m]
    DC
    APT
    2740.0
    [m]
    DC
    APT
    2743.0
    [m]
    DC
    APT
    2746.0
    [m]
    DC
    APT
    2749.0
    [m]
    DC
    APT
    2752.0
    [m]
    DC
    APT
    2755.0
    [m]
    DC
    APT
    2758.0
    [m]
    DC
    APT
    2761.0
    [m]
    DC
    APT
    2764.0
    [m]
    DC
    APT
    2767.0
    [m]
    DC
    APT
    2770.0
    [m]
    DC
    APT
    2773.0
    [m]
    DC
    APT
    2776.0
    [m]
    DC
    APT
    2779.0
    [m]
    DC
    APT
    2782.0
    [m]
    DC
    APT
    2785.0
    [m]
    DC
    APT
    2788.0
    [m]
    DC
    APT
    2791.0
    [m]
    DC
    APT
    2794.0
    [m]
    DC
    APT
    2797.0
    [m]
    DC
    APT
    2800.0
    [m]
    DC
    APT
    2809.0
    [m]
    DC
    APT
    2818.0
    [m]
    DC
    APT
    2827.0
    [m]
    DC
    APT
    2836.0
    [m]
    DC
    APT
    2845.0
    [m]
    DC
    APT
    2854.0
    [m]
    DC
    APT
    2863.0
    [m]
    DC
    APT
    2872.0
    [m]
    DC
    APT
    2881.0
    [m]
    DC
    APT
    2890.0
    [m]
    DC
    APT
    2899.0
    [m]
    DC
    APT
    2908.0
    [m]
    DC
    APT
    2917.0
    [m]
    DC
    APT
    2926.0
    [m]
    DC
    APT
    2935.0
    [m]
    DC
    APT
    2944.0
    [m]
    DC
    APT
    2953.0
    [m]
    DC
    APT
    2962.0
    [m]
    DC
    APT
    2971.0
    [m]
    DC
    APT
    2980.0
    [m]
    DC
    APT
    2989.0
    [m]
    DC
    APT
    2997.0
    [m]
    DC
    APT

  • Lithostratigraphy

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    AIT MSIP PPC TLD HNGS GR
    307
    1353
    AIT MSIP PPC TLD HNGS GR
    1055
    1464
    MDT GR
    1055
    1353
    MSIP GR
    1055
    1463
    MWD - GR RES
    352
    1055
    MWD - GR RES DEN NEU CALI
    1055
    3030
    MWD - GR RES FPWD SON
    1055
    3030
    MWD - MSIP TLD HNGS GR
    1055
    1353
    TLC MDT PPC GR
    1055
    1502

  • 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
    350.0
    36
    352.0
    0.00
    INTERM.
    13 3/8
    1045.0
    17 1/2
    1055.0
    0.00
    1058.0
    1058.0
    1.54
    FIT
    OPEN HOLE
    3030.0
    12 1/4
    3030.0
    0.00

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    1058
    1.43
    21.0
    EMS 4400
    1193
    1.32
    18.0
    EMS 4400
    1412
    1.43
    23.0
    EMS 4400
    1903
    1.33
    18.0
    EMS 4400
    2539
    1.33
    15.0
    EMS 4400
    2893
    1.33
    16.0
    EMS 4400
    3030
    1.39
    17.0
    EMS 4400