Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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01.11.2024 - 01:26
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6407/6-3

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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.
    6407/6-3
    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
    Multilateral
    Indicator telling if the parent well is multilateral, meaning it has more than one branch radiating from the main borehole. Example of legal values: YES, NO. See also Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    NO
    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.
    6407/6-3
    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.
    Den norske stats oljeselskap a.s
    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.
    533-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.
    66
    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,
    13.12.1986
    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.
    16.02.1987
    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.
    16.02.1989
    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.
    WILDCAT
    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.
    MIDDLE 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.
    FANGST GP
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    29.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    222.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3220.0
    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).
    3215.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    7
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    98
    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 TRIASSIC
    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° 42' 31.77'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    7° 40' 9.84'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7176849.07
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    436571.55
    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.
    1024

  • Wellbore history
    General
    Well 6407/6-3 was drilled on the eastern side of the Halten Terrace, roughly mid-way between the Draugen and Midgard Discoveries off shore mid-Norway. It was drilled on the same structure as well 6407/6-2, which was junked due to a disastrous shallow gas blow-out. The primary objective was to test for hydrocarbon accumulation in sandstones of Middle Jurassic age (Fangst Group). Secondary objectives were possible hydrocarbon accumulations in Early Jurassic sandstone, and to verify the geophysical and structural interpretation and improve the geological, paleontological and geochemical understanding of the area. Total depth was to be in rocks of Triassic age or 4000 m in order to satisfy the licence commitment.
    Operations and results
    Wildcat well 6407/6-3 was spudded with the semi-submersible installation Dyvi Delta on 13 December 1986 and drilled to TD at 3220 m in Late Triassic sediments of the Åre Formation. No significant technical problems were encountered in the operations, which were completed within planned time and budget. No shallow gas was encountered in the well. At 512 m, the interval thought to correspond with that which caused the uncontrolled blow out from well 6407/6-2, a small resistivity peak was recorded, although the gamma ray reading remained constant. A negative drilling break was recorded at the same depth but here was no increase in gas. The well was drilled with spud mud down to 459 m, with gypsum/polymer mud from 459 m to 2470 m, and with gel/lignite/lignosulphonate mud from 2470 m to TD.
    The Middle Jurassic sandstones were penetrated at 2461 m and were found to be gas/condensate bearing with a thin light oil leg. From FMT pressure gradients, logs and shows on cores an OWC can be set at 2583 m. There were shows and petroleum odour all through the reservoir down to 2583 m. Shows description, RFT pressure measurements,  DST results and geochemical analyses indicated a gas/light oil contact at ca 2570 - 2575  m.  Below 2583 m there was no fluorescence and only a weak, bluish white streaming cut. Sandstones of the Early Jurassic Tilje and Åre Formations were encountered at 2727 m. These were water wet without shows.
    Seven cores were cut in the Fangst Group from 2472 to 2615 m. No wire line fluid samples were taken.
    The well was permanently abandoned on 16 February 1987 as a gas/condensate discovery
    Testing
    Three drill stem tests were performed in the Fangst Group
    DST 1 tested the interval 2570 - 2577 m (later corrected to 2574.2 – 2581.2 m). It produced 338600 Sm3 gas, 151.6 Sm3 condensate and 20 - 45 m3 water /day through a 72/64" choke. GOR was 2233 Sm3/Sm3, the oil density was 0.810 g/cm3, the gas gravity was 0.760 (air = 1). The bottom hole temperature measured in the test was 93 deg C.
    DST 2 tested the interval 2546 - 2555 m (later corrected to 2550.2 – 2559.2 m). It produced 1249000 Sm3 gas, 512.7 Sm3 condensate and 1 m3 water /day through a 96/64" choke. GOR was 2437 Sm3/Sm3, the oil density was 0.737 g/cm3, the gas gravity was 0.723 (air = 1). The bottom hole temperature measured in the test was 98 deg C.
    DST 3 tested the interval 2479 - 2489 m (later corrected to 2483 – 2493 m). It produced 1298000 Sm3 gas, 517.7 Sm3 condensate /day through a 72/64" choke. No water was produced. GOR was 2507 Sm3/Sm3, the oil density was 0.752 g/cm3, the gas gravity was 0.742 (air = 1). The bottom hole temperature measured in the test was 96 deg C.

  • 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]
    470.00
    3220.00

  • 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
    2472.0
    2482.6
    [m ]
    2
    2491.0
    2509.4
    [m ]
    3
    2509.4
    2521.6
    [m ]
    4
    2522.0
    2545.0
    [m ]
    5
    2552.0
    2566.2
    [m ]
    6
    2575.0
    2584.4
    [m ]
    7
    2588.0
    2615.0
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    114.8
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 2472-2477m
    Core photo at depth: 2477-2482m
    Core photo at depth: 2482-2495m
    Core photo at depth: 2495-2500m
    Core photo at depth: 2500-2505m
    2472-2477m
    2477-2482m
    2482-2495m
    2495-2500m
    2500-2505m
    Core photo at depth: 2505-2509m
    Core photo at depth: 2509-2514m
    Core photo at depth: 2514-2519m
    Core photo at depth: 2519-2524m
    Core photo at depth: 2524-2529m
    2505-2509m
    2509-2514m
    2514-2519m
    2519-2524m
    2524-2529m
    Core photo at depth: 2529-2534m
    Core photo at depth: 2534-2539m
    Core photo at depth: 2539-2544m
    Core photo at depth: 2544-2558m
    Core photo at depth: 2556-2561m
    2529-2534m
    2534-2539m
    2539-2544m
    2544-2558m
    2556-2561m
    Core photo at depth: 2561-2566m
    Core photo at depth: 2566-2579m
    Core photo at depth: 2579-2584m
    Core photo at depth: 2584-2592m
    Core photo at depth: 2592-2597m
    2561-2566m
    2566-2579m
    2579-2584m
    2584-2592m
    2592-2597m
    Core photo at depth: 2597-2602m
    Core photo at depth: 2602-2607m
    Core photo at depth: 2607-2612m
    Core photo at depth: 2612-2615m
    Core photo at depth:  
    2597-2602m
    2602-2607m
    2607-2612m
    2612-2615m

  • 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
    TEST1
    2581.20
    2574.20
    31.01.1987 - 00:00
    YES
    DST
    TEST2
    2559.20
    2550.20
    05.02.1987 - 00:00
    YES
    DST
    TEST3
    2493.00
    2483.00
    10.02.1987 - 00:00
    YES

  • 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
    324.0
    36
    332.0
    0.00
    LOT
    SURF.COND.
    20
    430.0
    26
    459.0
    1.55
    LOT
    INTERM.
    13 3/8
    1391.0
    17 1/2
    1418.0
    1.95
    LOT
    INTERM.
    9 5/8
    2458.0
    12 1/4
    2470.0
    1.98
    LOT
    LINER
    7
    3083.0
    8 1/2
    3100.0
    1.89
    LOT

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    2570
    2577
    12.7
    2.0
    2546
    2555
    19.1
    3.0
    2479
    2489
    19.1
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    2.0
    3.0
    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
    115
    228000
    0.818
    0.770
    1979
    2.0
    260
    753000
    0.752
    0.755
    2897
    3.0
    326
    746000
    0.741
    0.720
    2288

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL
    1100
    2303
    CDL CN GR
    2455
    3217
    DIFL ACL GR
    430
    3090
    DIFL BHC ACL GR SON
    3078
    3217
    DIPLOG GR
    2455
    3090
    DLL MLL GR
    2455
    3090
    DTL
    1300
    2314
    FMT HP
    2455
    3018
    MWD - GR RES DIR
    430
    3100
    SPL
    2455
    3090
    SWC
    470
    538
    TL
    200
    900
    VSP
    466
    3181

  • Lithostratigraphy

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.13
    pdf
    5.43
    pdf
    0.45
    pdf
    9.45

  • 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
    10.02
    pdf
    3.17

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    459
    1.15
    7200.0
    8.5
    WATER BASED
    19.12.1986
    459
    1.15
    8800.0
    8.5
    WATER BASED
    22.12.1986
    459
    1.15
    8200.0
    8.9
    WATER BASED
    22.12.1986
    462
    1.15
    7200.0
    8.9
    WATER BASED
    22.12.1986
    545
    1.59
    6200.0
    5.1
    WATER BASED
    16.02.1987
    816
    1.17
    6400.0
    11.0
    WATER BASED
    23.12.1986
    1150
    1.16
    6300.0
    8.0
    WATER BASED
    29.12.1986
    1350
    1.17
    6300.0
    9.3
    WATER BASED
    29.12.1986
    1418
    1.19
    6500.0
    9.3
    WATER BASED
    29.12.1986
    1418
    1.19
    6000.0
    6.4
    WATER BASED
    29.12.1986
    1418
    1.25
    6000.0
    8.0
    WATER BASED
    29.12.1986
    1682
    1.50
    6700.0
    8.9
    WATER BASED
    29.12.1986
    1897
    1.60
    9000.0
    9.7
    WATER BASED
    30.12.1986
    2030
    1.63
    7000.0
    8.9
    WATER BASED
    02.01.1987
    2030
    1.63
    5900.0
    6.8
    WATER BASED
    02.01.1987
    2030
    1.63
    6900.0
    7.2
    WATER BASED
    05.01.1987
    2030
    1.63
    7400.0
    9.3
    WATER BASED
    05.01.1987
    2030
    1.63
    6800.0
    7.2
    WATER BASED
    05.01.1987
    2081
    1.63
    7800.0
    8.9
    WATERBASED
    02.01.1987
    2200
    1.20
    4800.0
    3.0
    WATER BASED
    13.02.1987
    2463
    1.20
    5800.0
    4.2
    WATER BASED
    12.01.1987
    2463
    1.20
    6000.0
    4.6
    WATER BASED
    14.01.1987
    2463
    1.20
    5000.0
    4.6
    WATER BASED
    08.01.1987
    2463
    1.20
    5000.0
    4.2
    WATER BASED
    09.01.1987
    2463
    1.20
    5600.0
    4.6
    WATER BASED
    12.01.1987
    2463
    1.20
    6700.0
    5.1
    WATER BASED
    12.01.1987
    2463
    1.20
    5700.0
    4.6
    WATER BASED
    13.01.1987
    2463
    1.20
    5800.0
    4.2
    WATER BASED
    15.01.1987
    2463
    1.20
    5800.0
    3.8
    WATER BASED
    16.01.1987
    2470
    1.20
    6000.0
    4.2
    WATER BASED
    19.01.1987
    2472
    1.25
    6200.0
    5.9
    WATER BASED
    06.01.1987
    2491
    1.25
    4800.0
    4.6
    WATER BASED
    07.01.1987
    2536
    1.20
    4300.0
    3.0
    WATER BASED
    09.02.1987
    2536
    1.20
    5200.0
    8.4
    WATER BASED
    09.02.1987
    2536
    1.20
    5200.0
    3.4
    WATER BASED
    10.02.1987
    2536
    1.20
    5000.0
    3.4
    WATER BASED
    11.02.1987
    2536
    1.20
    5000.0
    3.4
    WATER BASED
    12.02.1987
    2565
    1.20
    4800.0
    3.4
    WATER BASED
    09.02.1987
    2565
    1.20
    5100.0
    3.4
    WATER BASED
    02.02.1987
    2565
    1.20
    5000.0
    3.0
    WATER BASED
    03.02.1987
    2565
    1.20
    5100.0
    3.4
    WATER BASED
    04.02.1987
    2565
    1.20
    4500.0
    2.5
    WATER BASED
    05.02.1987
    2565
    1.20
    4400.0
    3.0
    WATER BASED
    09.02.1987
    2640
    1.20
    6500.0
    4.3
    WATERBASED
    27.01.1987
    2640
    1.20
    7400.0
    4.2
    WATER BASED
    28.01.1987
    2640
    1.20
    7500.0
    4.2
    WATER BASED
    29.01.1987
    2640
    1.20
    4000.0
    2.1
    WATER BASED
    30.01.1987
    2640
    0.00
    4500.0
    3.8
    WATERBASED
    02.02.1987
    2640
    1.20
    4500.0
    3.0
    WATER BASED
    02.02.1987
    3083
    1.20
    8400.0
    5.5
    WATER BASED
    19.01.1987
    3083
    1.20
    7500.0
    7.2
    WATER BASED
    19.01.1987
    3119
    1.20
    7400.0
    5.1
    WATER BASED
    21.01.1987
    3125
    1.20
    9000.0
    4.6
    WATER BASED
    21.01.1987
    3197
    1.20
    6600.0
    4.2
    WATER BASED
    22.01.1987
    3220
    1.20
    7100.0
    3.8
    WATER BASED
    23.01.1987
    3220
    1.20
    7200.0
    3.8
    WATER BASED
    26.01.1987
    3220
    1.20
    6200.0
    3.4
    WATER BASED
    26.01.1987
    3220
    1.20
    6800.0
    3.8
    WATER BASED
    26.01.1987