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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6407/9-2

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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.
    6407/9-2
    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
    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.
    6407/9-2
    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.
    443-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.
    77
    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,
    18.11.1984
    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.
    02.02.1985
    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.
    02.02.1987
    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.
    28.07.2007
    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
    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.
    247.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    1865.0
    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).
    1865.0
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    50
    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° 24' 1.31'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    7° 48' 11.26'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7142349.80
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    442297.15
    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.
    449

  • Wellbore history
    General
    Appraisal well 6407/9-2 was the second well in the Northern part of the Draugen Discovery on the Haltenbanken. The main objectives of the appraisal were to improve estimation of oil in place; to evaluate the reservoir quality and sand development on the Northern flank of the structure; calibration of the seismic time pick and velocity model; and to evaluate the oil deliverability and water injection characteristics.
    Operations and results
    Appraisal well 6407/9-2 was spudded with the semi-submersible installation Borgny Dolphin on 18 November 1984 and drilled to TD at 1865 m in the Early Jurassic Tilje Formation. The well was drilled with seawater and bentonite down to 813.5 m and with KCl/Polymer mud from 813.5 m to TD. No shallow gas was encountered.
    The Rogn Formation came in twenty m below prognosed depth at 1650 m. It consisted of an overall coarsening upwards sand sequence and contained an oil column of 12.5 m down to an oi1/ water contact at 1663.5 m. The calculated porosity was fairly constant throughout the reservoir at approximately 27%, while measured permeability decreased from up to 5 Darcy in the oil-bearing interval down to 20 mD towards the base of the reservoir. Eight conventional cores were cut from 1638 m to 1706.5 m. Several runs were made with the RFT: the reservoir pressure measured was hydrostatic, 2392 psia at 1625 m. No down hole fluid sample was recovered due to repeated plugging of the sampling probe.
    The well was permanently abandoned on 2 February as an oil appraisal
    Testing
    Two DST tests were performed. The water zone was perforated from 1670 to 1675.5 m. An eight hours water injection test at rates up to 8000 b/d did not reveal any immediate problems related to injection of unfiltered clean seawater. After the water zone test the oil zone was perforated from 1651 to 1657 m. The well was gravel packed and rates up to 1177 Sm3/day (7400 stb/d) of 40 deg API oil were achieved. The evaluation showed a permeability of 2.6 Darcy. The reservoir temperature was 67 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]
    360.00
    1866.00

  • 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
    1638.0
    1639.3
    [m ]
    2
    1640.0
    1641.0
    [m ]
    3
    1653.5
    1670.0
    [m ]
    4
    1671.5
    1680.7
    [m ]
    5
    1684.0
    1686.7
    [m ]
    6
    1688.0
    1693.8
    [m ]
    8
    1702.0
    1706.2
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    40.6
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 1638-1639m
    Core photo at depth: 1640-1641m
    Core photo at depth: 1653-1659m
    Core photo at depth: 1659-1665m
    Core photo at depth: 1665-1670m
    1638-1639m
    1640-1641m
    1653-1659m
    1659-1665m
    1665-1670m
    Core photo at depth: 1671-1677m
    Core photo at depth: 1677-1680m
    Core photo at depth: 1684-1686m
    Core photo at depth: 1688-1693m
    Core photo at depth: 1702-1706m
    1671-1677m
    1677-1680m
    1684-1686m
    1688-1693m
    1702-1706m

  • 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
    DST2
    1651.00
    1657.00
    16.01.1985 - 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
    346.0
    36
    350.0
    0.00
    SURF.COND.
    20
    800.0
    26
    810.0
    1.48
    LOT
    INTERM.
    13 3/8
    1575.0
    17 1/2
    1587.0
    1.67
    LOT
    INTERM.
    9 5/8
    1852.0
    12 1/4
    1865.0
    0.00

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    1670
    1676
    15.8
    2.0
    1651
    1657
    38.0
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    2.0
    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
    2.0
    1177
    43549
    0.825
    0.960
    37

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL VDL GR
    1054
    1799
    CBL VDL GR CCL
    450
    1574
    CNL GR
    1570
    1648
    DLL MSFL GR
    1574
    1858
    ISF LSS GR
    347
    812
    ISF LSS GR
    799
    1583
    ISF LSS GR
    1574
    1862
    LDL CNL GR
    347
    813
    LDL CNL GR
    799
    1583
    LDL CNL NGT
    1574
    1862
    RFT
    1652
    1745
    SHDT GR
    1574
    1863
    SWS
    1579
    1851
    VELOCITY
    524
    1850

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.32

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.52

  • 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
    5.14
    pdf
    0.97

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    352
    1.09
    8.0
    24.0
    WATER BASED
    22.11.1984
    810
    1.11
    5.0
    25.0
    WATER BASED
    23.11.1984
    810
    1.11
    6.0
    29.0
    WATER BASED
    26.11.1984
    810
    1.12
    5.0
    24.0
    WATER BASED
    26.11.1984
    810
    1.11
    8.0
    20.0
    WATER BASED
    27.11.1984
    810
    1.03
    WATER BASED
    28.11.1984
    810
    1.03
    WATER BASED
    29.11.1984
    810
    1.03
    WATER BASED
    30.11.1984
    810
    1.03
    WATER BASED
    04.12.1984
    810
    1.11
    6.0
    29.0
    WATER BASED
    26.11.1984
    810
    1.12
    5.0
    24.0
    WATER BASED
    26.11.1984
    810
    1.11
    8.0
    20.0
    WATER BASED
    27.11.1984
    810
    1.03
    WATER BASED
    28.11.1984
    810
    1.03
    WATER BASED
    29.11.1984
    810
    1.03
    WATER BASED
    30.11.1984
    810
    1.03
    WATER BASED
    04.12.1984
    1057
    1.33
    19.0
    21.0
    WATER BASED
    04.12.1984
    1233
    1.37
    18.0
    18.0
    WATER BASED
    04.12.1984
    1452
    1.41
    24.0
    20.0
    WATER BASED
    04.12.1984
    1584
    1.42
    25.0
    22.0
    WATER BASED
    05.12.1984
    1587
    1.25
    14.0
    14.0
    WATER BASED
    10.12.1984
    1587
    1.42
    24.0
    20.0
    WATER BASED
    06.12.1984
    1587
    1.42
    18.0
    25.0
    WATER BASED
    07.12.1984
    1587
    1.25
    16.0
    16.0
    WATER BASED
    10.12.1984
    1587
    1.25
    16.0
    15.0
    WATER BASED
    10.12.1984
    1587
    1.42
    14.0
    14.0
    WATER BASED
    11.12.1984
    1587
    1.42
    14.0
    14.0
    WATER BASED
    12.12.1984
    1587
    1.42
    WATER BASED
    12.12.1984
    1587
    1.42
    18.0
    25.0
    WATER BASED
    07.12.1984
    1587
    1.25
    16.0
    16.0
    WATER BASED
    10.12.1984
    1587
    1.25
    16.0
    15.0
    WATER BASED
    10.12.1984
    1587
    1.25
    14.0
    14.0
    WATER BASED
    10.12.1984
    1587
    1.42
    14.0
    14.0
    WATER BASED
    11.12.1984
    1587
    1.42
    14.0
    14.0
    WATER BASED
    12.12.1984
    1587
    1.42
    WATER BASED
    12.12.1984
    1604
    1.23
    15.0
    13.0
    WATER BASED
    17.12.1984
    1640
    1.23
    17.0
    15.0
    WATER BASED
    17.12.1984
    1654
    1.23
    17.0
    21.0
    WATER BASED
    17.12.1984
    1688
    1.23
    18.0
    18.0
    WATER BASED
    17.12.1984
    1702
    1.24
    16.0
    18.0
    WATER BASED
    19.12.1984
    1702
    1.24
    16.0
    18.0
    WATER BASED
    18.12.1984
    1812
    1.24
    16.0
    22.0
    WATER BASED
    18.12.1984
    1812
    1.24
    16.0
    22.0
    WATER BASED
    19.12.1984
    1865
    1.24
    18.0
    22.0
    WATER BASED
    26.12.1984
    1865
    1.24
    16.0
    18.0
    WATER BASED
    26.12.1984
    1865
    1.24
    17.0
    19.0
    WATER BASED
    26.12.1984
    1865
    1.03
    WATER BASED
    26.12.1984
    1865
    1.15
    WATER BASED
    01.01.1985
    1865
    1.24
    18.0
    22.0
    WATER BASED
    26.12.1984
    1865
    1.24
    16.0
    18.0
    WATER BASED
    26.12.1984
    1865
    1.24
    17.0
    19.0
    WATER BASED
    26.12.1984
    1865
    1.03
    WATER BASED
    26.12.1984
    1865
    1.14
    WATER BASED
    27.12.1984
    1865
    1.23
    18.0
    22.0
    WATER BASED
    20.12.1984
    1865
    1.14
    WATER BASED
    27.12.1984
    1865
    1.15
    WATER BASED
    01.01.1985

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    760.0
    [m]
    DC
    OD
    770.0
    [m]
    DC
    OD
    780.0
    [m]
    DC
    OD
    790.0
    [m]
    DC
    OD
    800.0
    [m]
    DC
    OD
    810.0
    [m]
    DC
    OD
    820.0
    [m]
    DC
    OD
    830.0
    [m]
    DC
    OD
    840.0
    [m]
    DC
    OD
    850.0
    [m]
    DC
    OD
    860.0
    [m]
    DC
    OD
    870.0
    [m]
    DC
    OD
    880.0
    [m]
    DC
    OD
    890.0
    [m]
    DC
    OD
    900.0
    [m]
    DC
    OD
    1638.0
    [m]
    C
    RRI
    1639.3
    [m]
    C
    RRI
    1640.0
    [m]
    C
    RRI
    1641.1
    [m]
    C
    RRI
    1663.2
    [m]
    C
    RRI
    1665.3
    [m]
    C
    RRI
    1666.1
    [m]
    C
    RRI
    1667.9
    [m]
    C
    RRI
    1674.4
    [m]
    C
    RRI
    1675.7
    [m]
    C
    RRI
    1677.2
    [m]
    C
    RRI
    1678.5
    [m]
    C
    RRI
    1679.7
    [m]
    C
    RRI
    1684.6
    [m]
    C
    RRI
    1685.9
    [m]
    C
    RRI
    1691.6
    [m]
    C
    RRI
    1702.0
    [m]
    C
    RRI
    1703.3
    [m]
    C
    RRI
    1703.8
    [m]
    C
    RRI
    1703.9
    [m]
    C
    RRI
    1704.6
    [m]
    C
    RRI
    1705.0
    [m]
    C
    RRI
    1705.5
    [m]
    C
    RRI