Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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05.11.2024 - 01:27
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6407/9-6

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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.
    6407/9-6
    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).
    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.
    SUSPENDED
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    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.
    6407/9-6
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    84-121 SP.228
    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.
    A/S Norske Shell
    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.
    499-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.
    71
    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,
    02.01.1986
    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.
    13.03.1986
    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.
    13.03.1988
    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.
    07.11.2005
    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.
    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.
    OIL
    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
    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.
    LATE 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.
    ROGN FM
    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.
    276.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    1800.0
    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).
    1796.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    1.9
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    57
    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.
    ROR FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    64° 19' 58.07'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    7° 44' 23.7'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7134880.01
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    439100.65
    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.
    871

  • Wellbore history
    General
    Well 6407/9-6 was drilled on the Draugen Field in the Haltenbanken area off shore Mid Norway. The target was the Rogn Sandstone Formation of the Late Jurassic. The objectives were to identify the western edge of the Rogn
    Formation, to establish the reservoir properties and development of the basal shale, to evaluate the water injection potential in oil-bearing sand, and to calibrate the seismic velocity.
    Operations and results
    Appraisal well 6407/9-6 was spudded with the semi-submersible installation Borgny Dolphin 2 January 1986 and drilled to TD at 1800 m in the Early Jurassic Ror Formation. Drilling proceeded without significant problems. The well was drilled with seawater and bentonite down to807 m, with KCl/polymer mud from 807 m to 1603 m, and with chalk mud from 1603 m to TD.
    The Rogn Formation was encountered oil-bearing from the top at 1642.5 m (1617.5 m SS) down to the base at 1660 m (1633.5 m SS). Average reservoir quality over this 17.5 m interval was very good, with calculated hydrocarbon saturation of 79 % and an average porosity of 31 %. Core permeabilities in the oil-bearing interval typically ranged between 1 and 10 Darcy. The underlying Fangst Group was interpreted as fully water bearing below 1671 m (1646 m SS), however low hydrocarbon saturations were calculated in the interval 1662 m to 1671 m (1637 - 1646 m SS). These were confirmed by the observed fluorescence in the cores over this interval and by Dean-Stark fluid saturation measurements.
    Four cores were cut in the interval 1646 - 1690.2 m. An FMT survey gave the same reservoir oil and water gradients as in the other wells on Draugen, and it was found that the Rogn Formation and the Fangst Group belong to the same pressure regime. One FMT fluid sample was taken at 1652.5 m in the Rogn Formation. After the well was plugged an intermittent stream of gas bubbles was observed leaking from the wellhead. Analysis of a sample of the gas showed that it consisted of methane only. The rig abandoned the location and a programme for regular monitoring of the wellhead and gas leak activity was initiated.
    The well was suspended as an oil appraisal and possible water injection well on 13 March 1986.
    Testing
    One DST test was performed in the Rogn Formation in the interval 1643 -1656 m. The test produced 1018 Sm3/day (6400 Stb/day) on a 56/64" choke. The GOR at separator was 18.4 Sm3/Sm3 (103 scf/stb), oil gravity was 40 deg API (0.825 g/cm3), gas gravity was 0.810 (air = 1), and CO2 content was 0.6%. Water injection in the same interval was tested with a maximum injection of 2385 Sm3/day (15000 bbl/day).

  • 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]
    390.00
    1800.00

  • 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
    1646.0
    1657.8
    [m ]
    2
    1660.0
    1672.7
    [m ]
    3
    1672.7
    1677.0
    [m ]
    4
    1678.8
    1690.3
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    40.2
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 1646-1651m
    Core photo at depth: 1651-1656m
    Core photo at depth: 1656-1657m
    Core photo at depth: 1660-1665m
    Core photo at depth: 1665-1670m
    1646-1651m
    1651-1656m
    1656-1657m
    1660-1665m
    1665-1670m
    Core photo at depth: 1670-1672m
    Core photo at depth: 1672-1677m
    Core photo at depth: 1678-1683m
    Core photo at depth: 1683-1688m
    Core photo at depth: 1688-1690m
    1670-1672m
    1672-1677m
    1678-1683m
    1683-1688m
    1688-1690m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1656.5
    [m]
    C
    RRI
    1656.8
    [m]
    C
    RRI
    1657.1
    [m]
    C
    RRI
    1657.8
    [m]
    C
    RRI
    1660.1
    [m]
    C
    RRI
    1660.3
    [m]
    C
    RRI
    1660.6
    [m]
    C
    RRI
    1661.0
    [m]
    C
    RRI
    1661.2
    [m]
    C
    RRI
    1661.7
    [m]
    C
    RRI
    1662.0
    [m]
    C
    RRI
    1662.2
    [m]
    C
    RRI
    1662.4
    [m]
    C
    RRI
    1662.4
    [m]
    C
    RRI
    1663.3
    [m]
    C
    RRI
    1671.4
    [m]
    C
    RRI
    1681.9
    [m]
    C
    RRI
    1684.4
    [m]
    C
    RRI
    1689.6
    [m]
    C
    RRI

  • 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
    SAMPLE8
    1637.00
    1646.00
    18.02.1986 - 00:00
    YES

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.39

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.75

  • 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
    8.93
    pdf
    0.82

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    ACL CBL VDL GR
    303
    1628
    ACL CBL VDL GR
    1055
    1735
    CDL CN GR
    365
    807
    CDL CN GR
    785
    1603
    CDL CNL GR
    1572
    1799
    CORGUN
    1624
    1787
    DIFL ACL GR
    278
    808
    DIFL ACL GR
    1572
    1799
    DIFL ACL SP
    675
    1607
    DIPLOG
    1616
    1794
    DLL MLL GR
    1612
    1795
    FMT HP
    1652
    1652
    VELOCITY
    378
    1787

  • 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
    375.0
    36
    382.0
    0.00
    LOT
    SURF.COND.
    20
    804.0
    26
    812.0
    1.44
    LOT
    INTERM.
    13 3/8
    1619.0
    17 1/2
    1628.0
    1.68
    LOT
    INTERM.
    9 5/8
    1776.0
    12 1/4
    1800.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    354
    1.03
    WATER BASED
    06.01.1986
    375
    1.03
    WATER BASED
    06.01.1986
    382
    1.06
    11.0
    16.0
    WATER BASED
    07.01.1986
    382
    1.03
    120.0
    WATER BASED
    06.01.1986
    416
    1.15
    WATER BASED
    10.03.1986
    416
    1.15
    WATER BASED
    11.03.1986
    416
    1.15
    WATER BASED
    12.03.1986
    484
    1.15
    65.0
    9.0
    WATER BASED
    25.05.1993
    609
    1.14
    36.0
    2.0
    WATER BASED
    28.05.1993
    613
    1.11
    11.0
    17.0
    WATER BASED
    08.01.1986
    810
    1.12
    11.0
    17.0
    WATER BASED
    09.01.1986
    810
    1.13
    12.0
    21.0
    WATER BASED
    09.01.1986
    810
    1.03
    WATER BASED
    13.01.1986
    812
    1.03
    WATER BASED
    13.01.1986
    812
    1.03
    WATER BASED
    14.01.1986
    812
    1.03
    WATER BASED
    12.01.1986
    817
    1.35
    23.0
    25.0
    WATER BASED
    16.01.1986
    860
    1.14
    36.0
    2.0
    WATER BASED
    02.06.1993
    860
    1.14
    34.0
    4.0
    WATER BASED
    25.05.1993
    860
    1.14
    36.0
    2.0
    WATER BASED
    28.05.1993
    1126
    1.37
    22.0
    27.0
    WATER BASED
    17.01.1986
    1376
    1.39
    31.0
    31.0
    WATER BASED
    20.01.1986
    1539
    1.39
    27.0
    22.0
    WATER BASED
    20.01.1986
    1554
    1.16
    35.0
    3.0
    WATER BASED
    25.05.1993
    1589
    1.14
    35.0
    2.0
    WATER BASED
    25.05.1993
    1589
    1.14
    34.0
    3.0
    WATER BASED
    25.05.1993
    1628
    1.39
    33.0
    29.0
    WATER BASED
    21.01.1986
    1628
    1.39
    31.0
    30.0
    WATER BASED
    20.01.1986
    1628
    1.39
    32.0
    21.0
    WATER BASED
    21.01.1986
    1628
    1.40
    33.0
    29.0
    WATER BASED
    30.01.1986
    1633
    1.40
    26.0
    37.0
    WATER BASED
    30.01.1986
    1641
    1.15
    WATER BASED
    10.03.1986
    1646
    1.20
    16.0
    19.0
    WATER BASED
    30.01.1986
    1660
    1.20
    16.0
    19.0
    WATER BASED
    30.01.1986
    1672
    1.20
    21.0
    26.0
    WATER BASED
    30.01.1986
    1678
    1.20
    18.0
    23.0
    WATER BASED
    30.01.1986
    1730
    1.15
    WATER BASED
    11.02.1986
    1738
    1.15
    WATER BASED
    11.02.1986
    1738
    1.15
    WATER BASED
    12.02.1986
    1738
    1.15
    WATER BASED
    10.02.1986
    1738
    1.15
    WATER BASED
    14.02.1986
    1738
    1.15
    WATER BASED
    16.02.1986
    1738
    1.15
    WATER BASED
    20.02.1986
    1738
    1.15
    WATER BASED
    21.02.1986
    1738
    1.15
    WATER BASED
    24.02.1986
    1738
    1.15
    WATER BASED
    27.02.1986
    1738
    1.15
    WATER BASED
    28.02.1986
    1738
    1.15
    WATER BASED
    03.03.1986
    1738
    1.15
    WATER BASED
    04.03.1986
    1738
    1.15
    WATER BASED
    07.03.1986
    1738
    1.15
    WATER BASED
    07.03.1986
    1738
    1.03
    WATER BASED
    04.02.1986
    1738
    1.15
    WATER BASED
    06.02.1986
    1738
    1.15
    WATER BASED
    11.02.1986
    1738
    1.15
    WATER BASED
    17.02.1986
    1738
    1.15
    WATER BASED
    05.03.1986
    1750
    1.20
    20.0
    27.0
    WATER BASED
    30.01.1986
    1800
    1.21
    19.0
    26.0
    WATER BASED
    30.01.1986
    1800
    1.21
    20.0
    28.0
    WATER BASED
    03.02.1986
    1800
    1.21
    21.0
    30.0
    WATER BASED
    03.02.1986
    1800
    1.21
    20.0
    30.0
    WATER BASED
    31.01.1986
    1800
    1.21
    21.0
    22.0
    WATER BASED
    03.02.1986

  • 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
    0.25