Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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22.12.2024 - 01:25
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6406/3-5

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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.
    6406/3-5
    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).
    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
    Well name
    Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    6406/3-5
    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.
    576-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,
    03.04.1988
    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.
    01.06.1988
    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.
    01.06.1990
    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.
    18.05.2004
    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.
    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.
    29.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    302.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4283.0
    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).
    4281.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    4.5
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    92
    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.
    TILJE FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    64° 58' 20.07'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    6° 58' 33.65'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7207070.27
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    404464.42
    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.
    1227

  • Wellbore history
    General
    Well 6406/3-5 was designed to explore the Lambda structure and was the first well on the structure. The Lambda structure is a flat-lying horst situated in the NE corner of the block.
    The primary purpose of the well was to find hydrocarbon accumulations of significant amounts in the Middle and Lower Jurassic sandstones of the Fangst Group and Tilje Formation. Secondary objectives were to verify the interpretation regarding the structural closure towards north, and to verify the geophysical and structural interpretation and improve the geological, paleontological and geochemical understanding of the area. The well was planned to TD in the Åre Formation.
    Operations and results
    Wildcat well 6406/3-5 was spudded with Smedvig Drilling semi-submersible rig West Delta on 3 April 1988 and drilled to a total depth of 4283 m in the Early Jurassic Tilje Formation. Shallow gas was registered at 570 m. After pulling out to cement this zone, it was impossible to get back into the hole again. After a new spud 3 May, the 30" was set at 418 m, and 20" at 538 m. A new shallow gas zone was registered at 813 m, and the mud was weighted to 1.35 g/cm. The circulation was lost at 1116 m, and the section was cemented. After this drilling progressed with a mud weight of 1.25 g/cm3. This resulted in lost circulation at 1340 m. Both times it was assumed that that the circulation was lost in the zone around 562 m. The hole was cemented back and drilled to 607 m where a new leak-off test up to 1.34 g/cm was performed. This time there were no problems with the drilling to 1749 m (setting depth of 9 5/8" casing) with mud weight of 1.25 g/CM3. Further drilling to TD proceeded without significant problems. The well was drilled with spud mud down to 545 m, with gypsum/polymer mud from 545 m to 3841 m, and with gel/lignite/lignosulphonate mud from 3841 m to TD.
    Top Fangst was encountered at 3817 m. There were weak shows in the top ten meters of the Garn Formation down to 3825 m, with increased resistivity on MWD down to approx. 3828 m. One run was done using Western Atlas FMT with HP and strain gauge. A total of 25 pre test points were measured. By drawing a line through pressure points in the Garn Formation, it gave a gradient of 0.99 g/cc. A normal water gradient of 1.02 g/cc was not achieved due to unstable pressure points in the lower Garn Formation. A pressure shift in the Ile Formation of approximately 75 psi (0.52 Mpa) was observed in the data. It was not possible to draw a gradient line due to few points in the Ile Formation, but a water gradient was interpreted. The Tilje Formation was found to be tight and interpreted as water bearing. One sample was taken in the upper Garn Formation at 3821 m. The sample contained a mixture of formation water and mud filtrate with traces of oil and gas. The chloride concentration of 9100 mg/1 was found to be approximately three times higher than the chloride concentration from the mud filtrate (3000 mg/1). One core was cut in the interval 3815 m to 3837 m in the Garn Formation. As the well was not obligatory, and after it was observed that the Tilje Formation sandstones did not contain any hydrocarbons, the TD of the well was revised to TD in the lower part of the Tilje Formation instead of in the Åre Formation. The well was permanently abandoned on 1 June 1988 as a well with shows.
    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]
    550.00
    4281.00

  • 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
    3815.0
    3836.0
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    21.0
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 3815-3820m
    Core photo at depth: 3820-3825m
    Core photo at depth: 3825-3830m
    Core photo at depth: 3830-3835m
    Core photo at depth: 3835-3836m
    3815-3820m
    3820-3825m
    3825-3830m
    3830-3835m
    3835-3836m

  • 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
    418.0
    36
    473.0
    0.00
    LOT
    SURF.COND.
    20
    535.0
    26
    545.0
    1.43
    LOT
    INTERM.
    13 3/8
    1722.0
    17 1/2
    1749.0
    1.77
    LOT
    INTERM.
    9 5/8
    3797.0
    12 1/4
    3814.0
    1.93
    LOT
    OPEN HOLE
    4283.0
    8 1/2
    0.0
    0.00
    LOT

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL VDL GR
    778
    1722
    CDL CN SPL
    3795
    4289
    DIFL ACL GR CDL
    537
    1712
    DIFL BHC GR
    3795
    4289
    DIFL BHC GR CDL
    1722
    3796
    DIPLOG
    3795
    4289
    FMT GR
    3795
    4289
    MWD - GR RES ROP DIR
    334
    4280
    VSP
    334
    4200

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.77

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.86

  • 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
    19.29

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    236
    1.04
    100.0
    WATER BASED
    12.05.1987
    236
    1.09
    WATER BASED
    12.05.1987
    348
    1.03
    WATER BASED
    05.04.1988
    380
    1.03
    WATER BASED
    31.05.1988
    400
    1.04
    100.0
    WATER BASED
    12.05.1987
    418
    1.10
    WATER BASED
    05.04.1988
    473
    1.05
    WATER BASED
    06.04.1988
    475
    1.03
    WATER BASED
    05.04.1988
    545
    1.20
    WATER BASED
    07.04.1988
    545
    1.20
    45.0
    5.0
    WATER BASED
    11.04.1988
    545
    1.03
    WATER BASED
    08.04.1988
    577
    1.23
    49.0
    5.0
    WATER BASED
    15.04.1988
    610
    1.20
    15.0
    4.0
    WATER BASED
    30.05.1988
    723
    1.04
    WATER BASED
    12.05.1987
    723
    1.04
    WATER BASED
    14.05.1987
    723
    1.07
    48.0
    WATER BASED
    19.05.1987
    723
    1.17
    WATER BASED
    19.05.1987
    823
    1.20
    53.0
    6.0
    WATER BASED
    13.04.1988
    873
    1.19
    37.0
    11.0
    WATER BASED
    20.05.1987
    905
    1.20
    51.0
    7.5
    WATER BASED
    11.04.1988
    1116
    1.20
    53.0
    5.5
    WATER BASED
    12.04.1988
    1116
    1.20
    47.0
    5.5
    WATER BASED
    12.04.1988
    1123
    1.26
    42.0
    12.5
    WATER BASED
    20.05.1987
    1276
    1.31
    38.0
    10.1
    WATER BASED
    21.05.1987
    1325
    1.69
    55.0
    7.5
    WATER BASED
    30.05.1988
    1352
    1.23
    48.0
    6.0
    WATER BASED
    14.04.1988
    1614
    1.23
    11.0
    3.0
    WATER BASED
    18.04.1988
    1749
    1.26
    15.0
    3.0
    WATER BASED
    18.04.1988
    1749
    1.25
    13.0
    6.0
    WATER BASED
    18.04.1988
    1756
    1.70
    21.0
    4.0
    WATER BASED
    20.04.1988
    2102
    1.70
    22.0
    6.0
    WATER BASED
    21.04.1988
    2102
    1.60
    18.0
    3.0
    WATER BASED
    22.04.1988
    2288
    1.68
    61.0
    6.0
    WATER BASED
    27.04.1988
    2318
    1.69
    55.0
    7.5
    WATER BASED
    30.05.1988
    2370
    1.69
    52.0
    6.0
    WATER BASED
    27.04.1988
    2370
    1.69
    65.0
    8.5
    WATER BASED
    16.05.1988
    2370
    1.69
    64.0
    9.0
    WATER BASED
    27.04.1988
    2370
    1.69
    59.0
    7.5
    WATER BASED
    27.04.1988
    2370
    1.69
    53.0
    8.0
    WATER BASED
    27.04.1988
    2370
    1.69
    54.0
    7.5
    WATER BASED
    28.04.1988
    2370
    1.69
    52.0
    7.5
    WATER BASED
    29.04.1988
    2370
    1.69
    66.0
    9.5
    WATER BASED
    09.05.1988
    2370
    1.69
    58.0
    10.0
    WATER BASED
    09.05.1988
    2370
    1.69
    58.0
    11.0
    WATER BASED
    09.05.1988
    2370
    1.69
    58.0
    10.0
    WATER BASED
    13.05.1988
    2370
    1.70
    55.0
    10.0
    WATER BASED
    13.05.1988
    2370
    1.69
    53.0
    9.5
    WATER BASED
    13.05.1988
    2370
    1.69
    58.0
    10.5
    WATER BASED
    10.05.1988
    2370
    1.69
    50.0
    8.5
    WATER BASED
    16.05.1988
    2370
    1.69
    60.0
    9.0
    WATER BASED
    16.05.1988
    2370
    1.69
    48.0
    6.0
    WATER BASED
    18.05.1988
    2370
    1.69
    60.0
    5.5
    WATER BASED
    18.05.1988
    2370
    1.69
    68.0
    5.0
    WATER BASED
    19.05.1988
    3208
    1.69
    28.0
    8.0
    WATER BASED
    02.05.1988
    3228
    1.69
    29.0
    8.0
    WATER BASED
    02.05.1988
    3303
    1.69
    26.0
    9.0
    WATER BASED
    02.05.1988
    3367
    1.69
    24.0
    10.0
    WATER BASED
    03.05.1988
    3437
    1.69
    24.0
    10.0
    WATER BASED
    04.05.1988
    3456
    1.69
    25.0
    10.0
    WATER BASED
    05.05.1988
    3456
    1.69
    24.0
    9.0
    WATER BASED
    06.05.1988
    3623
    1.69
    49.0
    5.5
    WATER BASED
    27.05.1988
    3815
    1.24
    52.0
    3.0
    WATER BASED
    20.05.1988
    3856
    1.24
    41.0
    7.0
    WATER BASED
    26.05.1988
    3906
    1.24
    19.0
    3.0
    WATER BASED
    24.05.1988
    4073
    1.24
    21.0
    4.0
    WATER BASED
    24.05.1988
    4140
    1.24
    27.0
    3.0
    WATER BASED
    24.05.1988
    4283
    1.24
    27.0
    3.5
    WATER BASED
    24.05.1988
    4283
    1.24
    27.0
    3.5
    WATER BASED
    25.05.1988

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    2000.0
    [m]
    DC
    RRI
    2010.0
    [m]
    DC
    RRI
    2030.0
    [m]
    DC
    RRI
    2050.0
    [m]
    DC
    RRI
    2070.0
    [m]
    DC
    RRI
    2090.0
    [m]
    DC
    RRI
    2110.0
    [m]
    DC
    RRI
    2130.0
    [m]
    DC
    RRI
    2150.0
    [m]
    DC
    RRI
    2170.0
    [m]
    DC
    RRI
    2190.0
    [m]
    DC
    RRI
    2210.0
    [m]
    DC
    RRI
    2230.0
    [m]
    DC
    RRI
    2250.0
    [m]
    DC
    RRI
    2262.0
    [m]
    DC
    RRI
    2280.0
    [m]
    DC
    RRI
    2292.0
    [m]
    DC
    RRI
    2310.0
    [m]
    DC
    RRI
    2322.0
    [m]
    DC
    RRI
    2340.0
    [m]
    DC
    RRI
    2352.0
    [m]
    DC
    RRI
    2370.0
    [m]
    DC
    RRI
    2382.0
    [m]
    DC
    RRI
    2400.0
    [m]
    DC
    RRI
    2412.0
    [m]
    DC
    RRI
    2430.0
    [m]
    DC
    RRI
    2442.0
    [m]
    DC
    RRI
    2460.0
    [m]
    DC
    RRI
    2472.0
    [m]
    DC
    RRI
    2490.0
    [m]
    DC
    RRI
    2502.0
    [m]
    DC
    RRI
    2520.0
    [m]
    DC
    RRI
    2532.0
    [m]
    DC
    RRI
    2550.0
    [m]
    DC
    RRI
    2562.0
    [m]
    DC
    RRI
    2580.0
    [m]
    DC
    RRI
    2592.0
    [m]
    DC
    RRI
    2610.0
    [m]
    DC
    RRI
    2622.0
    [m]
    DC
    RRI
    2640.0
    [m]
    DC
    RRI
    2802.0
    [m]
    DC
    RRI
    2817.0
    [m]
    DC
    RRI
    2832.0
    [m]
    DC
    RRI
    2847.0
    [m]
    DC
    RRI
    2862.0
    [m]
    DC
    RRI
    2877.0
    [m]
    DC
    RRI
    2952.0
    [m]
    DC
    RRI
    2967.0
    [m]
    DC
    RRI
    2982.0
    [m]
    DC
    RRI
    2997.0
    [m]
    DC
    RRI
    3012.0
    [m]
    DC
    RRI
    3027.0
    [m]
    DC
    RRI
    3042.0
    [m]
    DC
    RRI
    3057.0
    [m]
    DC
    RRI
    3072.0
    [m]
    DC
    RRI
    3087.0
    [m]
    DC
    RRI
    3102.0
    [m]
    DC
    RRI
    3117.0
    [m]
    DC
    RRI
    3135.0
    [m]
    DC
    RRI
    3150.0
    [m]
    DC
    RRI
    3165.0
    [m]
    DC
    RRI
    3180.0
    [m]
    DC
    RRI
    3195.0
    [m]
    DC
    RRI
    3675.0
    [m]
    DC
    RRI
    3693.0
    [m]
    DC
    RRI
    3823.9
    [m]
    C
    RRI
    3831.7
    [m]
    C
    RRI
    3939.0
    [m]
    DC
    RRI
    3954.0
    [m]
    DC
    RRI
    3969.0
    [m]
    DC
    RRI
    3984.0
    [m]
    DC
    RRI
    4014.0
    [m]
    DC
    RRI
    4059.0
    [m]
    DC
    RRI
    4089.0
    [m]
    DC
    RRI
    4119.0
    [m]
    DC
    RRI
    4134.0
    [m]
    DC
    RRI
    4164.0
    [m]
    DC
    RRI
    4179.0
    [m]
    DC
    RRI
    4194.0
    [m]
    DC
    RRI
    4209.0
    [m]
    DC
    RRI
    4224.0
    [m]
    DC
    RRI
    4239.0
    [m]
    DC
    RRI
    4254.0
    [m]
    DC
    RRI
    4263.0
    [m]
    DC
    RRI
    4281.0
    [m]
    DC
    RRI