Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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27.11.2024 - 01:27
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6407/7-5

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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.
    6407/7-5
    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.
    6407/7-5
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    NH 8604- Row 342 & COL. 655
    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.
    660-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.
    61
    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,
    17.12.1990
    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.
    15.02.1991
    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.
    15.02.1993
    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.
    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.
    24.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    327.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3725.0
    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).
    3716.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    11.3
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    140
    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° 18' 24.34'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    7° 10' 50.58'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7132634.02
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    411996.50
    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.
    1699

  • Wellbore history
    General
    The Njord Field is situated in the southern part of the Haltenbanken area in a down faulted position relative to the Trøndelag Platform and the Frøya High. Oil had been encountered in previous wells on Njord in the Ile, Tilje, and Åre Formations. Well 6407/7-5 is located on the North II fault segment on the North Flank of the Njord structure. The main objectives for the well were to test the resource potential of the Northern Flank, to clarify the number of production and injection wells needed for development, and to verify the reservoir quality and the sealing potential of faults. The pore pressure gradient was expected to be maximum 1.54 rd in the reservoir. Shallow gas warnings were given for 6 levels down to 650 m. Planned TD was 3725 m
    Operations and results
    Well 6407/7-5 was spudded with the semi-submersible installation Transocean 8 on 15 February 1991 and drilled to TD at 3725 m in Early Jurassic sediments of the Åre Formation. After coring the interval 3168 - 3215m the drilling assembly got stuck when running in the hole. Fishing the drilling assembly failed and the well was subsequently plugged back and side tracked from 3080 m. Indications of shallow gas were found in two of the six warned levels. The well was drilled with spud mud down to 1112 m and with KCl/polymer mud from 1112 m to TD.
    The reservoir sandstones of the Ile, Ror and Tilje Formations were found to be water bearing. RFT pressures and one segregated sample indicated very poor permeabilities in the sandstone intervals tested. From the data it was not possible to determine whether pressure communication exists between 6407/7-5 and 6407/7-3.
    Sporadic oil shows were recorded on sandstone stringers in the Nise Formation below 2267 m. Weak oil shows were recorded on claystones, limestones and sandstones of the Lysing Formation between 3000 - 3084 m. This interval also had high gas readings with gas peaks up to 10%. Some oil shows were seen on sandstones from 3163.5 to 3274 m in the Ile and Ror Formations. The deepest recorded show while drilling was at 3360 m in the Tilje Formation. Organic geochemical analyses confirmed that migrated hydrocarbons were present in the Cromer Knoll Group, and the Ile and Tilje Formations.
    A total of five conventional cores were cut in the well. Fifteen side wall cores were attempted and 5 were recovered. The RFT sample at 3412.8 m recovered only mud filtrate.
    The well was permanently abandoned on 15 February 1991 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]
    1120.00
    3725.00

  • 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
    3075.0
    3083.7
    [m ]
    2
    3168.0
    3195.5
    [m ]
    3
    3195.5
    3214.5
    [m ]
    4
    3359.0
    3383.0
    [m ]
    5
    3410.0
    3437.0
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    106.2
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 3075-3080m
    Core photo at depth: 3080-3083m
    Core photo at depth: 3168-3173m
    Core photo at depth: 3173-3178m
    Core photo at depth: 3178-3183m
    3075-3080m
    3080-3083m
    3168-3173m
    3173-3178m
    3178-3183m
    Core photo at depth: 3183-3188m
    Core photo at depth: 3188-3193m
    Core photo at depth: 3193-3197m
    Core photo at depth: 3197-3202m
    Core photo at depth: 3202-3207m
    3183-3188m
    3188-3193m
    3193-3197m
    3197-3202m
    3202-3207m
    Core photo at depth: 3207-3212m
    Core photo at depth: 3212-3214m
    Core photo at depth: 3359-3364m
    Core photo at depth: 3364-3369m
    Core photo at depth: 3369-3374m
    3207-3212m
    3212-3214m
    3359-3364m
    3364-3369m
    3369-3374m
    Core photo at depth: 3374-3379m
    Core photo at depth: 3379-3383m
    Core photo at depth: 3410-3415m
    Core photo at depth: 3415-3420m
    Core photo at depth: 3420-3425m
    3374-3379m
    3379-3383m
    3410-3415m
    3415-3420m
    3420-3425m
    Core photo at depth: 3425-3430m
    Core photo at depth: 3430-3435m
    Core photo at depth: 3435-3437m
    Core photo at depth:  
    Core photo at depth:  
    3425-3430m
    3430-3435m
    3435-3437m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1180.0
    [m]
    DC
    RRI
    1240.0
    [m]
    DC
    RRI
    1300.0
    [m]
    DC
    RRI
    1330.0
    [m]
    DC
    RRI
    1390.0
    [m]
    DC
    RRI
    1420.0
    [m]
    DC
    RRI
    1450.0
    [m]
    DC
    RRI
    1750.0
    [m]
    DC
    RRI
    1870.0
    [m]
    DC
    RRI
    1900.0
    [m]
    DC
    RRI
    1930.0
    [m]
    DC
    RRI
    2035.0
    [m]
    DC
    RRI
    2050.0
    [m]
    DC
    RRI
    2070.0
    [m]
    DC
    RRI
    2130.0
    [m]
    DC
    RRI
    2530.0
    [m]
    DC
    RRI
    2560.0
    [m]
    DC
    RRI
    2590.0
    [m]
    DC
    RRI
    2640.0
    [m]
    DC
    RRI
    2650.0
    [m]
    DC
    RRI
    2660.0
    [m]
    DC
    RRI
    2670.0
    [m]
    DC
    RRI
    2680.0
    [m]
    DC
    RRI
    2690.0
    [m]
    DC
    RRI
    2700.0
    [m]
    DC
    RRI
    2710.0
    [m]
    DC
    RRI
    2730.0
    [m]
    DC
    RRI
    2750.0
    [m]
    DC
    RRI
    2770.0
    [m]
    DC
    RRI
    2780.0
    [m]
    DC
    RRI
    2795.0
    [m]
    DC
    RRI
    2825.0
    [m]
    DC
    RRI
    2830.0
    [m]
    DC
    RRI
    2840.0
    [m]
    DC
    RRI
    2850.0
    [m]
    DC
    RRI
    2860.0
    [m]
    DC
    RRI
    2875.0
    [m]
    DC
    RRI
    2880.0
    [m]
    DC
    RRI
    2890.0
    [m]
    DC
    RRI
    2900.0
    [m]
    DC
    RRI
    2910.0
    [m]
    DC
    RRI
    2920.0
    [m]
    DC
    RRI
    2930.0
    [m]
    DC
    RRI
    2940.0
    [m]
    DC
    RRI
    2950.0
    [m]
    DC
    RRI
    2960.0
    [m]
    DC
    RRI
    2970.0
    [m]
    C
    HYDRO
    2980.0
    [m]
    DC
    RRI
    2990.0
    [m]
    DC
    RRI
    3005.0
    [m]
    DC
    RRI
    3010.0
    [m]
    DC
    RRI
    3020.0
    [m]
    DC
    RRI
    3035.0
    [m]
    DC
    RRI
    3040.0
    [m]
    DC
    RRI
    3050.0
    [m]
    DC
    RRI
    3060.0
    [m]
    DC
    RRI
    3070.0
    [m]
    DC
    RRI
    3075.0
    [m]
    C
    RRI
    3077.0
    [m]
    C
    HYDRO
    3083.7
    [m]
    C
    RRI
    3090.0
    [m]
    C
    HYDRO
    3100.0
    [m]
    DC
    RRI
    3110.0
    [m]
    DC
    RRI
    3122.0
    [m]
    C
    HYDRO
    3130.0
    [m]
    DC
    RRI
    3140.0
    [m]
    DC
    RRI
    3155.0
    [m]
    DC
    RRI
    3160.0
    [m]
    DC
    RRI
    3168.0
    [m]
    C
    RRI
    3169.5
    [m]
    C
    RRI
    3175.0
    [m]
    C
    RRI
    3185.0
    [m]
    C
    RRI
    3196.0
    [m]
    C
    RRI
    3206.0
    [m]
    C
    RRI
    3214.5
    [m]
    C
    RRI
    3280.0
    [m]
    DC
    RRI
    3290.0
    [m]
    DC
    RRI
    3300.0
    [m]
    DC
    RRI
    3310.0
    [m]
    DC
    RRI
    3320.0
    [m]
    DC
    RRI
    3330.0
    [m]
    DC
    RRI
    3340.0
    [m]
    DC
    RRI
    3350.0
    [m]
    DC
    RRI
    3359.0
    [m]
    C
    RRI
    3365.6
    [m]
    C
    RRI
    3371.0
    [m]
    C
    RRI
    3378.5
    [m]
    C
    RRI
    3381.0
    [m]
    C
    RRI
    3413.0
    [m]
    C
    RRI
    3426.0
    [m]
    C
    RRI
    3431.8
    [m]
    C
    RRI
    3435.0
    [m]
    C
    RRI
    3436.0
    [m]
    C
    RRI
    3447.0
    [m]
    DC
    RRI
    3460.0
    [m]
    DC
    RRI
    3470.0
    [m]
    DC
    RRI
    3490.0
    [m]
    DC
    RRI
    3530.0
    [m]
    DC
    RRI
    3540.0
    [m]
    DC
    RRI
    3560.0
    [m]
    DC
    RRI
    3570.0
    [m]
    DC
    RRI
    3580.0
    [m]
    DC
    RRI
    3590.0
    [m]
    DC
    RRI
    3600.0
    [m]
    DC
    RRI
    3610.0
    [m]
    DC
    RRI
    3620.0
    [m]
    DC
    RRI
    3680.0
    [m]
    DC
    RRI
    3720.0
    [m]
    DC
    RRI

  • Lithostratigraphy

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.16
    pdf
    1.30

  • 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
    14.76

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CST
    3970
    3122
    DIL LSS LDL CNL GR SP AMS
    2859
    3719
    DIL LSS LDL SP GR AMS
    1097
    2870
    FMS4 GR AMS
    2859
    3719
    LWD - GR RES DIR
    439
    3725
    MWD - GR RES DIR
    351
    394
    RFT GR AMS
    3004
    3171
    RFTB HP GR AMS
    3166
    3254
    RFTB HP GR AMS
    3412
    3412
    RFTB HP GR AMS
    3433
    3433
    VSP
    2840
    3510
    VSP
    2970
    3122

  • 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
    435.0
    36
    437.0
    0.00
    LOT
    INTERM.
    13 3/8
    1097.0
    17 1/2
    1100.0
    1.49
    LOT
    INTERM.
    9 5/8
    2859.0
    12 1/4
    2866.0
    1.45
    LOT
    OPEN HOLE
    3725.0
    8 1/2
    3725.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    380
    1.60
    38.0
    16.0
    WATER BASED
    08.02.1991
    380
    1.60
    38.0
    16.0
    WATER BASED
    08.02.1991
    650
    1.05
    WATER BASED
    27.12.1990
    1112
    1.20
    WATER BASED
    27.12.1990
    1112
    1.40
    19.0
    10.0
    WATER BASED
    27.12.1990
    1112
    1.40
    20.0
    11.0
    WATER BASED
    27.12.1990
    1400
    1.46
    23.0
    13.0
    WATER BASED
    27.12.1990
    1902
    1.60
    28.0
    10.0
    WATER BASED
    27.12.1990
    2272
    1.60
    26.0
    10.0
    WATER BASED
    28.12.1990
    2519
    1.60
    21.0
    10.0
    WATER BASED
    03.01.1991
    2588
    1.60
    24.0
    10.0
    WATER BASED
    03.01.1991
    2723
    1.60
    24.0
    12.0
    WATER BASED
    03.01.1991
    2795
    1.61
    48.0
    23.0
    WATER BASED
    07.02.1991
    2824
    1.60
    26.0
    12.0
    WATER BASED
    03.01.1991
    2826
    1.60
    28.0
    11.0
    WATER BASED
    03.01.1991
    2834
    1.60
    20.0
    8.0
    WATER BASED
    03.01.1991
    2866
    1.60
    25.0
    11.0
    WATER BASED
    07.01.1991
    2870
    1.45
    26.0
    8.0
    WATER BASED
    09.01.1991
    2870
    1.45
    26.0
    8.0
    WATER BASED
    08.01.1991
    2870
    1.45
    18.0
    8.0
    WATER BASED
    11.01.1991
    2964
    1.45
    26.0
    10.0
    WATER BASED
    14.01.1991
    3026
    1.64
    29.0
    10.0
    WATER BASED
    23.01.1991
    3049
    1.40
    31.0
    12.0
    WATER BASED
    14.01.1991
    3075
    1.64
    27.0
    10.0
    WATER BASED
    14.01.1991
    3084
    1.67
    29.0
    9.0
    WATER BASED
    15.01.1991
    3090
    1.64
    31.0
    18.0
    WATER BASED
    25.01.1991
    3134
    1.64
    27.0
    8.0
    WATER BASED
    25.01.1991
    3168
    1.64
    29.0
    10.0
    WATER BASED
    16.01.1991
    3195
    1.64
    28.0
    10.0
    WATER BASED
    17.01.1991
    3214
    1.64
    28.0
    10.0
    WATER BASED
    18.01.1991
    3214
    1.64
    30.0
    10.0
    WATER BASED
    21.01.1991
    3214
    1.64
    29.0
    10.0
    WATER BASED
    21.01.1991
    3214
    1.64
    29.0
    9.0
    WATER BASED
    21.01.1991
    3359
    1.64
    30.0
    10.0
    WATER BASED
    29.01.1991
    3383
    1.64
    30.0
    8.0
    WATER BASED
    29.01.1991
    3410
    1.64
    29.0
    8.0
    WATER BASED
    29.01.1991
    3437
    1.64
    30.0
    11.0
    WATER BASED
    30.01.1991
    3716
    1.64
    27.0
    10.0
    WATER BASED
    30.01.1991
    3725
    1.64
    26.0
    10.0
    WATER BASED
    31.01.1991
    3725
    1.64
    27.0
    9.0
    WATER BASED
    01.02.1991
    3725
    1.64
    26.0
    9.0
    WATER BASED
    05.02.1991
    3725
    1.63
    28.0
    10.0
    WATER BASED
    05.02.1991
    3725
    1.63
    29.0
    10.0
    WATER BASED
    05.02.1991
    3725
    1.63
    29.0
    10.0
    WATER BASED
    06.02.1991
    3725
    1.63
    28.0
    10.0
    WATER BASED
    05.02.1991

  • 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