Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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sodir.no          Norsk
22.12.2024 - 01:25
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6403/10-1

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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.
    6403/10-1
    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.
    6403/10-1
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    xline:NH003-4698 Inline:NH003-3446
    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.
    Norsk Hydro Produksjon 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.
    1041-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.
    68
    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,
    24.10.2002
    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.
    30.12.2002
    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.
    30.12.2004
    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.
    11.02.2005
    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.
    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.
    25.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    1717.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3400.0
    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).
    3397.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    6.3
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    80
    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 CRETACEOUS
    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.
    KVITNOS FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    64° 3' 39.22'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    3° 0' 10.88'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7103975.31
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    500147.51
    UTM zone
    Universal Transverse Mercator zone. Examples of legal values: 31, 32, 33, 34.
    31
    NPDID wellbore
    Norwegian Offshore Directorate's unique id for the wellbore.
    4602

  • Wellbore history
    General
    The exploration well 6403/10-1 was drilled to test the hydrocarbon potential in one of the segments of the PL 253 Solsikke dome structure. The Solsikke structure is situated in the north-western part of the outer Møre Basin, close to the Møre Marginal High, in the Norwegian Sea. The structure is defined as a large Tertiary dome comprising a thickness anomaly of Upper Cretaceous sediments. The primary target was the Nise and Intra Springar sandstones and the secondary target was the Intra Kvitnos sandstones. The well was drilled in a relatively low structural position on the southern part of the dome. The location was chosen to test the hydrocarbon potential above a clear flat event within the Nise Formation and at the same time penetrate the Springar in a position of anticipated good Springar reservoir quality near observed flat events within the Springar. The well should also test the intra Kvitnos Formation, but avoid faults within the formations and shallow gas observations. In addition, the spud location had to take into account the rough sea bottom.
    Operations and results
    Exploration well 6403/10-1 was spudded with the semi-submersible installation Scarabeo 5 on 24 October 2002 and drilled to TD at 3398 m in the Kvitnos Formation. No serious problems were encountered during drilling. The well was drilled with spud mud down to 2217 m and with a water-based glycol system (GLYDRIL) from 2217 m to TD.
    Mudstone and siltstone were encountered in the Cretaceous reservoir section, with high content of siltstone in Nise. Sidewall cores of the siltstone in the Nise Formation showed high porosity but low permeability with no reservoir quality. The well did not prove any hydrocarbons. Organic geochemical analyses indicated immature formations throughout the well based on Rock-Eval Tmax and vitrinite reflectance readings. No significant amounts of C15+ hydrocarbons were detected in these analyses, confirming the on-rig shows analyses. There were however recorded traces of ?supermature? hydrocarbon gasses and gasoline range hydrocarbons (C1 to C9) in the interval 2500 m to 2800 m, indicating a migration pathway at this level. The well was not conventionally cored since the coring criteria were not met. Forty-eight sidewall cores were recovered. No pressure points were recorded on wire line and no fluid samples taken.
    The well was permanently abandoned as dry on 30 December 2002.
    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]
    2200.00
    3400.00

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    2217.0
    [m]
    DC
    RRI
    2226.0
    [m]
    DC
    RRI
    2235.0
    [m]
    DC
    RRI
    2244.0
    [m]
    DC
    RRI
    2253.0
    [m]
    DC
    RRI
    2262.0
    [m]
    DC
    RRI
    2271.0
    [m]
    DC
    RRI
    2280.0
    [m]
    DC
    RRI
    2289.0
    [m]
    DC
    RRI
    2298.0
    [m]
    DC
    RRI
    2307.0
    [m]
    DC
    RRI
    2316.0
    [m]
    DC
    RRI
    2325.0
    [m]
    DC
    RRI
    2334.0
    [m]
    DC
    RRI
    2340.0
    [m]
    DC
    RRI
    2349.0
    [m]
    DC
    RRI
    2361.0
    [m]
    DC
    RRI
    2370.0
    [m]
    DC
    RRI
    2379.0
    [m]
    DC
    RRI
    2382.0
    [m]
    DC
    RRI
    2391.0
    [m]
    DC
    RRI
    2400.0
    [m]
    DC
    RRI
    2409.0
    [m]
    DC
    RRI
    2418.0
    [m]
    DC
    RRI
    2427.0
    [m]
    DC
    RRI
    2436.0
    [m]
    DC
    RRI
    2445.0
    [m]
    DC
    RRI
    2454.0
    [m]
    DC
    RRI
    2463.0
    [m]
    DC
    RRI
    2472.0
    [m]
    DC
    RRI
    2481.0
    [m]
    DC
    RRI
    2490.0
    [m]
    DC
    RRI
    2499.0
    [m]
    DC
    RRI
    2508.0
    [m]
    DC
    RRI
    2517.0
    [m]
    DC
    RRI
    2526.0
    [m]
    DC
    RRI
    2535.0
    [m]
    DC
    RRI
    2544.0
    [m]
    DC
    RRI
    2553.0
    [m]
    DC
    RRI
    2562.0
    [m]
    DC
    RRI
    2571.0
    [m]
    DC
    RRI
    2580.0
    [m]
    DC
    RRI
    2592.0
    [m]
    DC
    RRI
    2601.0
    [m]
    DC
    RRI
    2610.0
    [m]
    DC
    RRI
    2619.0
    [m]
    DC
    RRI
    2628.0
    [m]
    DC
    RRI
    2637.0
    [m]
    DC
    RRI
    2646.0
    [m]
    DC
    RRI
    2655.0
    [m]
    DC
    RRI
    2664.0
    [m]
    DC
    RRI
    2673.0
    [m]
    DC
    RRI
    2682.0
    [m]
    DC
    RRI
    2691.0
    [m]
    DC
    RRI
    2700.0
    [m]
    DC
    RRI
    2709.0
    [m]
    DC
    RRI
    2718.0
    [m]
    DC
    RRI
    2727.0
    [m]
    DC
    RRI
    2736.0
    [m]
    DC
    RRI
    2745.0
    [m]
    DC
    RRI
    2754.0
    [m]
    DC
    RRI
    2763.0
    [m]
    DC
    RRI
    2772.0
    [m]
    DC
    RRI
    2781.0
    [m]
    DC
    RRI
    2790.0
    [m]
    DC
    RRI
    2799.0
    [m]
    DC
    RRI
    2808.0
    [m]
    DC
    RRI
    2817.0
    [m]
    DC
    RRI
    2826.0
    [m]
    DC
    RRI
    2835.0
    [m]
    DC
    RRI
    2843.0
    [m]
    DC
    RRI
    2858.0
    [m]
    SWC
    RRI
    2867.0
    [m]
    SWC
    RRI
    2871.0
    [m]
    SWC
    RRI
    2878.0
    [m]
    SWC
    RRI
    2882.0
    [m]
    SWC
    RRI
    2884.0
    [m]
    SWC
    RRI
    2894.0
    [m]
    SWC
    RRI
    2907.0
    [m]
    DC
    RRI
    2912.0
    [m]
    SWC
    RRI
    2925.0
    [m]
    DC
    RRI
    2934.0
    [m]
    DC
    RRI
    2936.0
    [m]
    SWC
    RRI
    2943.0
    [m]
    DC
    RRI
    2952.0
    [m]
    DC
    RRI
    2959.0
    [m]
    SWC
    RRI
    2961.0
    [m]
    DC
    RRI
    2970.0
    [m]
    DC
    RRI
    2975.0
    [m]
    SWC
    RRI
    2979.0
    [m]
    DC
    RRI
    2988.0
    [m]
    DC
    RRI
    2997.0
    [m]
    DC
    RRI
    3006.0
    [m]
    DC
    RRI
    3008.0
    [m]
    SWC
    RRI
    3015.0
    [m]
    DC
    RRI
    3024.0
    [m]
    DC
    RRI
    3028.0
    [m]
    SWC
    RRI
    3033.0
    [m]
    DC
    RRI
    3042.0
    [m]
    DC
    RRI
    3051.0
    [m]
    DC
    RRI
    3060.0
    [m]
    DC
    RRI
    3063.0
    [m]
    SWC
    RRI
    3069.0
    [m]
    DC
    RRI
    3078.0
    [m]
    DC
    RRI
    3087.0
    [m]
    DC
    RRI
    3096.0
    [m]
    DC
    RRI
    3105.0
    [m]
    DC
    RRI
    3114.0
    [m]
    DC
    RRI
    3123.0
    [m]
    DC
    RRI
    3132.0
    [m]
    DC
    RRI
    3141.0
    [m]
    DC
    RRI
    3150.0
    [m]
    DC
    RRI
    3152.0
    [m]
    SWC
    RRI
    3159.0
    [m]
    DC
    RRI
    3168.0
    [m]
    DC
    RRI
    3177.0
    [m]
    DC
    RRI
    3186.0
    [m]
    DC
    RRI
    3195.0
    [m]
    DC
    RRI
    3204.0
    [m]
    DC
    RRI
    3213.0
    [m]
    DC
    RRI
    3222.0
    [m]
    DC
    RRI
    3231.0
    [m]
    DC
    RRI
    3240.0
    [m]
    DC
    RRI
    3249.0
    [m]
    DC
    RRI
    3258.0
    [m]
    DC
    RRI
    3267.0
    [m]
    DC
    RRI
    3276.0
    [m]
    DC
    RRI
    3285.0
    [m]
    DC
    RRI
    3297.0
    [m]
    DC
    RRI
    3306.0
    [m]
    DC
    RRI
    3315.0
    [m]
    DC
    RRI
    3324.0
    [m]
    DC
    RRI
    3333.0
    [m]
    DC
    RRI
    3342.0
    [m]
    DC
    RRI
    3351.0
    [m]
    DC
    RRI
    3360.0
    [m]
    DC/SWC
    RRI
    3369.0
    [m]
    DC
    RRI
    3378.0
    [m]
    DC
    RRI
    3380.0
    [m]
    SWC
    RRI
    3387.0
    [m]
    DC
    RRI
    3393.0
    [m]
    SWC
    RRI
    3396.0
    [m]
    DC
    RRI
    3400.0
    [m]
    DC
    RRI

  • Lithostratigraphy
    Lithostratigraphy
    Top depth [mMD RKB]
    Lithostrat. unit
    1742
    1742
    1904
    2015
    2015
    2250
    2250
    2334
    2496
    2496
    2825
    3098

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.24

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    1.66

  • 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
    2.11
    .PDF
    5.53

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    DSI GR
    1742
    2625
    HRLA PEX DSI GR
    2848
    3393
    MSCT GR
    2848
    3393
    MWD LWD - GR GEO VISDN ISON PWD
    2843
    3400
    MWD LWD - GR GEOVIS VISDN PWD DI
    2522
    2842
    MWD LWD - GR RES ARC ISON DIR
    2207
    2503
    MWD LWD - GR RES CDR DIR
    1817
    2214
    MWD LWD - PP
    1742
    1852
    MWD LWD - PP ARC
    2522
    2838
    VSI GR
    1680
    2640
    VSI GR
    2521
    3390
    ZO VSP
    421
    3390

  • 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
    1833.0
    36
    1852.0
    0.00
    LOT
    INTERM.
    20
    2207.0
    26
    2214.0
    1.14
    LOT
    INTERM.
    13 3/8
    2510.0
    17 1/2
    2518.0
    1.24
    LOT
    INTERM.
    9 5/8
    2830.0
    12 1/4
    2843.0
    1.27
    LOT
    OPEN HOLE
    3400.0
    8 1/2
    3400.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    1775
    1.23
    20.0
    WATER BASED
    1852
    1.05
    WATER BASED
    2035
    1.22
    20.0
    WATER BASED
    2214
    1.05
    WATER BASED
    2518
    1.11
    11.0
    WATER BASED
    2522
    1.12
    11.0
    WATER BASED
    2670
    1.22
    21.0
    WATER BASED
    2842
    1.18
    21.0
    WATER BASED
    2922
    1.20
    21.0
    WATER BASED
    3305
    1.21
    21.0
    WATER BASED
    3400
    1.21
    21.0
    WATER BASED