Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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31.12.2024 - 01:26
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6407/7-6

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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.
    6407/7-6
    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
    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.
    6407/7-6
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    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.
    985-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.
    60
    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,
    18.10.2000
    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.
    16.12.2000
    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.
    16.12.2002
    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.
    18.12.2002
    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.
    GAS/CONDENSATE
    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.
    YES
    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 JURASSIC
    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.
    TILJE FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    26.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    336.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3975.0
    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).
    3971.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    9.58
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    148
    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° 17' 40.66'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    7° 6' 16.31'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7131389.98
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    408271.69
    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.
    4172

  • Wellbore history
    General
    Well 6407/7-6 is located within Njord Unit on the western flank of the Njord Field. The northwest flank structure consists of five fault blocks defined by faults trending south-southwest and north-northeast, with throw towards west. The objective for the well 6407/7-6 was to test the hydrocarbon potential of the "B-segment" on the northwest flank of the Njord field. The primary target was to test the hydrocarbon potential of the Tilje formation of the Båt Group, while the hydrocarbon potential of the Ile Formation of the Fangst Group was a secondary target. There existed also a possibility of hydrocarbons in the Upper Jurassic Melke formation of the Viking Group, and in the Lower Cretaceous Lange Formation of the Cromer Knoll Group.
    Operations and results
    Wildcat well 6407/7-6 was spudded with the semi-submersible installation "Scarabeo 6" on 18 October 2000. First spud failed due to boulders and high angle in the hole. After a second spud on October 19 the well was first drilled to TD at 3930 m in the Early Jurassic Åre Formation. The TD was later extended to 3975 m to get space for test equipment. The extended TD was not logged. Shallow gas was not encountered. The well was drilled with water based bentonite mud down 1231 m and with oil based mud (Versavert) from 1231 m to TD. The main result of the well was the discovery of gas-condensate in the Tilje Formation as proven by a DST and by MDT fluid samples. The well penetrated 127 m Late Jurassic, 111 m Ile Formation, and 197 m Tilje Formation. The sands encountered in the Lange Formation, the Viking Group, and the Ile Formation were water bearing, but hydrocarbon shows were observed in the approximate 20 m net Lange sandstone and increasing amounts of background gas was measured while drilling in the upper part of the Ile Formation. The Tilje Formation was saturated with a heavy gas-condensate from 3693 m down to a Gas/Water Contact at 3777 m, determined from the resistivity log. Six cores were cut in the Tilje Formation with a recovery of 98% giving a total of 129m. Horizontal Klinkenberg corrected permeability in the range of 0.02 - 12.2 mD was measured in the cores. The core porosity seldom exceeded 20%. Pressure measurements from both the Ile and the Tilje Formations indicate an approximate overpressure of 160-170 bar on the B-segment compared to the Njord East flank. MDT fluid sampling was attempted in the Tilje, Lange and the Ile formations. No samples could be taken in Lange and Ile formations due to tight formations. In the Tilje Formation five samples were retrieved from 3748 m. The short clean-up time prior to sampling caused the samples to be highly contaminated with base oil from the drilling mud (30 % & 60 % base oil). The well was plugged and abandoned as an oil discovery on 16 December 2000.
    Testing
    The well was production tested with a perforation interval between 3686-3770 m in the Tilje Formation. With 24 hours production the flow rate was measured to 155 000 Sm3/D gas and 220 Sm3/D oil. The GOR was 705 Sm3/Sm3.

  • 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]
    1240.00
    3930.00

  • 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
    3701.0
    3707.6
    [m ]
    2
    3743.0
    3769.0
    [m ]
    3
    3770.5
    3785.7
    [m ]
    4
    3786.0
    3808.7
    [m ]
    5
    3809.0
    3837.3
    [m ]
    6
    3837.4
    3864.9
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    126.2
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 3701-3706m
    Core photo at depth: 3706-3746m
    Core photo at depth: 3746-3751m
    Core photo at depth: 3751-3756m
    Core photo at depth: 3756-3761m
    3701-3706m
    3706-3746m
    3746-3751m
    3751-3756m
    3756-3761m
    Core photo at depth: 3761-3766m
    Core photo at depth: 3766-3771m
    Core photo at depth: 3771-3776m
    Core photo at depth: 3776-3781m
    Core photo at depth: 3781-3785m
    3761-3766m
    3766-3771m
    3771-3776m
    3776-3781m
    3781-3785m
    Core photo at depth: 3786-3791m
    Core photo at depth: 3791-3796m
    Core photo at depth: 3796-3801m
    Core photo at depth: 3801-3806m
    Core photo at depth: 3806-3811m
    3786-3791m
    3791-3796m
    3796-3801m
    3801-3806m
    3806-3811m
    Core photo at depth: 3811-3816m
    Core photo at depth: 3816-3821m
    Core photo at depth: 3821-3826m
    Core photo at depth: 3826-3831m
    Core photo at depth: 3831-3836m
    3811-3816m
    3816-3821m
    3821-3826m
    3826-3831m
    3831-3836m
    Core photo at depth: 3836-3840m
    Core photo at depth: 3840-3845m
    Core photo at depth: 3845-3850m
    Core photo at depth: 3850-3855m
    Core photo at depth: 3855-3860m
    3836-3840m
    3840-3845m
    3845-3850m
    3850-3855m
    3855-3860m
    Core photo at depth: 3860-3865m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    3860-3865m

  • 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
    DST 1
    3726.00
    0.00
    01.12.2000 - 00:00
    YES

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.46

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    1.88
    pdf
    1.67

  • 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
    1.52
    .PDF
    9.52
    .PDF
    3.38
    .PDF
    3.77
    .PDF
    0.67
    .PDF
    0.56

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    3686
    3770
    16.0
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    52.450
    136
    Drill stem tests (DST)
    Test number
    Oil
    [Sm3/day]
    Gas
    [Sm3/day]
    Oil density
    [g/cm3]
    Gas grav. rel.air
    GOR
    [m3/m3]
    1.0
    220
    155000
    0.815
    705

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    AIT IPLT /LDS APS HNGS
    3093
    3930
    CMR ESC VSP
    2900
    3913
    CMR+
    3440
    3882
    CST
    3125
    3900
    MDT
    3880
    3925
    MSCT
    0
    0
    MWD - CDR GR RES PWD DIR
    365
    3100
    MWD - RAB CDR GR RES DEN PWD
    3100
    3930
    UBI DSI
    2900
    3925

  • 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
    446.5
    36
    449.0
    0.00
    LOT
    SURF.COND.
    20
    1224.0
    26
    1229.0
    1.80
    LOT
    INTERM.
    9 5/8
    3094.0
    12 1/4
    3100.0
    1.76
    LOT
    OPEN HOLE
    3975.0
    8 1/2
    3975.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    386
    1.05
    WATER BASED
    392
    0.00
    WATER BASED
    900
    0.00
    OIL BASED
    1232
    1.60
    72.0
    OIL BASED
    2541
    1.60
    38.0
    OIL BASED
    2900
    1.61
    50.0
    OIL BASED
    3083
    1.60
    44.0
    OIL BASED
    3100
    1.60
    45.0
    OIL BASED
    3205
    1.60
    44.0
    OIL BASED
    3377
    1.61
    42.0
    OIL BASED
    3558
    1.60
    33.0
    OIL BASED
    3700
    1.60
    33.0
    OIL BASED
    3709
    1.62
    33.0
    OIL BASED
    3720
    1.60
    34.0
    OIL BASED
    3743
    1.61
    34.0
    OIL BASED
    3771
    1.61
    33.0
    OIL BASED
    3786
    1.61
    37.0
    OIL BASED
    3809
    1.61
    36.0
    OIL BASED
    3852
    1.61
    36.0
    OIL BASED
    3864
    1.61
    34.0
    OIL BASED
    3975
    1.61
    46.0
    OIL BASED

  • 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
    0.29