Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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22.11.2024 - 09:09
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6407/9-5

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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.
    6407/9-5
    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).
    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.
    RE-CLASS TO DEV
    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.
    6407/9-5
    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.
    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.
    482-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.
    63
    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,
    12.09.1985
    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.
    13.11.1985
    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.
    13.11.1987
    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.
    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.
    APPRAISAL
    Reclassified to wellbore
    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.
    33.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    286.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    1820.0
    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).
    1819.0
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    48
    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.
    MIDDLE 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.
    NOT FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    64° 16' 42.35'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    7° 44' 14.66'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7128824.58
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    438858.99
    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.
    492

  • Wellbore history
    General
    Well 6407/9-5 was the fifth well drilled on the Draugen Field in the southern Haltenbanken area. Wells 6407/9-1, 6407/9-2 and 6407/9-3 delineated an areally extensive oil accumulation in relatively thin Late Jurassic Rogn Formation sandstone. Net oil sand thicknesses in these wells were 39, 12 and 34 m respectively. The oil gravity was 40 deg API. Well 6407/9-4, located on the west flank of the northern accumulation, confirmed pinch out of the Rogn Formation and encountered similar oil in the underlying Garn formation. The initial conditions of pressure and oil water contact in this well (1638.5 m MSL were similar to those in the Rogn Formation accumulation. The objectives of well 6407/9-5 were to delineate top structure and rock qualities in the southern culmination. Prognosed TD was 1805 m in rocks of Triassic age, or a maximum depth of 4000 m.
    Operations and results
    Appraisal well 6407/9-5 was spudded with the semi-submersible installation West Venture on 12 September 1985 and drilled to TD at 1820 m in the Early Jurassic Not Formation. Drilling proceeded without serious problems, except for the sections trough glacial deposits were huge boulders caused minor problems. The well was drilled vertical. Deepest reported deviation survey was at 1675 m (1675 m TVD RKB). To this depth maximum deviation from vertical was 0.66 deg. The well was drilled with seawater and bentonite down to 811 m, with KCl/polymer mud from 811 m to 1625 m, and with chalk mud from 1625 m to TD.
    The Rogn Formation was encountered at 1654 m, 15 m deeper than prognosed. Light oil was discovered, as known from the other wells in the Draugen field. The oi1/water contact was found at 1671 m (1639 m MSL), the same contact as in the other wells drilled on the Draugen Field. Average reservoir quality over this 17 m interval was good, with a calculated hydrocarbon saturation of 76% and a porosity of 27%. Core permeabilities from the oil interval typically ranged between 1 and 10 Darcy. The base of the Rogn Formation, from 1704.0 - 1734.0 was laminated, bituminous shales with occasionally sandy and silty beds, which were strongly pyrite cemented. This interval forms a thick impermeable layer between the Rogn and the underlying Garn sands. The underlying water bearing Garn Formation contained 32 m of sandstone with 32 % average porosity. Oil shows were recorded only in the Rogn Formation reservoir from top and down to 1675 m. No shows were seen elsewhere in the well.
    Four cores were cut in the interval 1654 - 1703 m in the Rogn Formation. No fluid samples were acquired on wire line, although several attempts were made.
    On completion of the testing the well was suspended on 13 November 1985 as a possible future oil producer. It was re-entered in April 1993. It was taken in use as an oil producer and renamed 6407/9-A-55 H.
    Testing
    One DST test was performed in the interval 1654 - 1661 m (1621 to 1628 m MSL).
    The well produced up to a maximum of 1210 Sm3 oil /day of 40 deg API oil through a 1" choke. Separator GOR was measured at 18.2 Sm3/Sm3. The gas gravity was 0.818 (air = 1) with 0.35% CO2 and 0 ppm H2S. Initial reservoir pressure was calculated as 2394 psia at 1663 m (1630 m MSL). The previously established Draugen reservoir pressure of 2392 psia (at datum) was within the accuracy of the gauges.

  • 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]
    420.00
    1820.00

  • 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
    1654.3
    1668.7
    [m ]
    2
    1671.0
    1672.9
    [m ]
    3
    1674.0
    1683.7
    [m ]
    4
    1685.0
    1701.4
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    42.4
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 1654-1659m
    Core photo at depth: 1659-1664m
    Core photo at depth: 1664-1668m
    Core photo at depth: 1671-1672m
    Core photo at depth: 1674-1679m
    1654-1659m
    1659-1664m
    1664-1668m
    1671-1672m
    1674-1679m
    Core photo at depth: 1679-1683m
    Core photo at depth: 1685-1690m
    Core photo at depth: 1690-1695m
    Core photo at depth: 1790-1695m
    Core photo at depth: 1695-1700m
    1679-1683m
    1685-1690m
    1690-1695m
    1790-1695m
    1695-1700m
    Core photo at depth: 1685-1701m
    Core photo at depth: 1700-1701m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    1685-1701m
    1700-1701m

  • 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
    DST1
    1654.00
    1661.00
    30.10.1985 - 01:30
    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
    396.0
    36
    408.0
    0.00
    LOT
    CONDUCTOR
    30
    408.0
    36
    408.0
    0.00
    LOT
    SURF.COND.
    20
    801.0
    26
    811.0
    1.52
    LOT
    INTERM.
    13 3/8
    1617.0
    17 1/2
    1625.0
    1.72
    LOT
    INTERM.
    9 5/8
    1800.0
    12 1/4
    1820.0
    0.00
    LOT

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    1654
    1661
    25.4
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    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
    1203
    23000
    0.825
    0.785
    17

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL
    1193
    1679
    CBL VDL
    1150
    1680
    DLL MSFL GR
    1617
    1811
    GR
    1300
    1625
    GR
    1550
    1604
    ISF LSS GR
    317
    810
    ISF LSS GR
    803
    1606
    ISF LSS GR
    1617
    1815
    LDL CNL GR
    397
    811
    LDL CNL GR
    803
    1606
    LDL CNL NGS
    1617
    1816
    RFT
    1617
    1807
    RFT
    1658
    1760
    RFT
    1658
    1760
    SHDT
    1617
    1810
    SWS
    1100
    1605
    SWS
    1618
    1807
    WST
    489
    1800

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.34

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    1.27
    pdf
    0.19
    pdf
    0.48

  • 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
    5.16
    pdf
    0.92

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    408
    1.04
    120.0
    WATER BASED
    16.09.1985
    420
    1.25
    WATER BASED
    11.11.1985
    420
    1.25
    WATER BASED
    12.11.1985
    520
    1.04
    60.0
    WATER BASED
    16.09.1985
    811
    1.09
    80.0
    WATER BASED
    17.09.1985
    811
    1.09
    120.0
    WATER BASED
    18.09.1985
    811
    1.04
    120.0
    WATER BASED
    19.09.1985
    811
    1.03
    WATER BASED
    20.09.1985
    811
    1.03
    WATER BASED
    23.09.1985
    908
    1.35
    47.0
    26.0
    WATER BASED
    23.09.1985
    1220
    1.40
    50.0
    27.0
    WATER BASED
    24.09.1985
    1220
    1.40
    24.0
    24.0
    WATER BASED
    25.09.1985
    1595
    1.15
    WATER BASED
    07.11.1985
    1595
    1.15
    WATER BASED
    11.11.1985
    1616
    1.40
    20.0
    21.0
    WATER BASED
    26.09.1985
    1619
    1.15
    WATER BASED
    05.11.1985
    1619
    1.15
    WATER BASED
    06.11.1985
    1625
    1.40
    21.0
    22.0
    WATER BASED
    27.09.1985
    1625
    1.40
    22.0
    23.0
    WATER BASED
    30.09.1985
    1625
    1.40
    23.0
    23.0
    WATER BASED
    30.09.1985
    1654
    1.20
    16.0
    24.0
    WATER BASED
    01.10.1985
    1660
    1.19
    47.0
    27.0
    WATER BASED
    07.10.1985
    1674
    1.20
    21.0
    28.0
    WATER BASED
    02.10.1985
    1679
    1.18
    18.0
    22.0
    WATER BASED
    09.10.1985
    1684
    1.18
    13.0
    14.0
    WATER BASED
    10.10.1985
    1688
    1.15
    WATER BASED
    14.10.1985
    1688
    1.15
    WATER BASED
    15.10.1985
    1688
    1.15
    WATER BASED
    16.10.1985
    1688
    1.15
    WATER BASED
    17.10.1985
    1688
    1.15
    WATER BASED
    18.10.1985
    1688
    1.15
    WATER BASED
    21.10.1985
    1688
    1.15
    WATER BASED
    22.10.1985
    1688
    1.15
    WATER BASED
    23.10.1985
    1688
    1.15
    WATER BASED
    24.10.1985
    1688
    1.15
    WATER BASED
    28.10.1985
    1688
    1.15
    WATER BASED
    29.10.1985
    1688
    1.15
    WATER BASED
    31.10.1985
    1688
    1.15
    WATER BASED
    04.11.1985
    1688
    1.15
    WATER BASED
    11.10.1985
    1689
    1.15
    WATER BASED
    14.10.1985
    1703
    1.20
    22.0
    29.0
    WATER BASED
    03.10.1985
    1788
    1.19
    20.0
    27.0
    WATER BASED
    08.10.1985
    1820
    1.20
    21.0
    29.0
    WATER BASED
    04.10.1985
    1820
    1.20
    23.0
    23.0
    WATER BASED
    07.10.1985

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1250.0
    [m]
    DC
    FUGRO
    1260.0
    [m]
    DC
    FUGRO
    1270.0
    [m]
    DC
    FUGRO
    1280.0
    [m]
    DC
    FUGRO
    1290.0
    [m]
    DC
    FUGRO
    1300.0
    [m]
    DC
    FUGRO
    1310.0
    [m]
    DC
    FUGRO
    1320.0
    [m]
    DC
    FUGRO
    1330.0
    [m]
    DC
    FUGRO
    1340.0
    [m]
    DC
    FUGRO
    1350.0
    [m]
    DC
    FUGRO
    1360.0
    [m]
    DC
    FUGRO
    1370.0
    [m]
    DC
    FUGRO
    1380.0
    [m]
    DC
    FUGRO
    1390.0
    [m]
    DC
    FUGRO
    1400.0
    [m]
    DC
    FUGRO
    1410.0
    [m]
    DC
    FUGRO
    1420.0
    [m]
    DC
    FUGRO
    1657.5
    [m]
    C
    APT
    1660.8
    [m]
    C
    APT
    1672.4
    [m]
    C
    APT
    1674.3
    [m]
    C
    APT
    1683.3
    [m]
    C
    APT
    1699.7
    [m]
    C
    APT
    1700.4
    [m]
    C
    APT
    1700.7
    [m]
    C
    APT
    1701.0
    [m]
    C
    APT
    1701.4
    [m]
    C
    APT

  • Thin sections at the Norwegian Offshore Directorate
    Thin sections at the Norwegian Offshore Directorate
    Depth
    Unit
    1638.00
    [m ]