Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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6407/9-4

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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.
    6407/9-4
    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
    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.
    6407/9-4
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    84 - 117 A SP. 630
    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.
    472-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.
    69
    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,
    04.07.1985
    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.
    10.09.1985
    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.
    10.09.1987
    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
    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
    2nd level with HC, age
    Age of lithostratigraphic unit, 2nd level, where hydrocarbons were encountered. Examples of legal values: CRETACEOUS, EARLY CRETACEOUS, LATE JURASSIC, EOCENE.
    MIDDLE JURASSIC
    2nd level with HC, formation
    Name of lithostartigraphic unit, 2nd 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.
    GARN FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    32.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    244.0
    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).
    1820.0
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    47
    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° 22' 14'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    7° 43' 21.84'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7139103.84
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    438354.84
    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.
    480

  • Wellbore history
    General
    Appraisal well 6407/9-4 is the fourth well on the Draugen Field. The main objective was the Late Jurassic Rogn Formation. Wells 6407/9-1, 6407/9-2 and 6407/9-3 had previously encountered under-saturated 40 deg API oil in sandstones of the Late Jurassic Rogn Formation. Net oil sand thicknesses in the three previous wells were 39, 12 and 34 m, respectively. Precise definition of the OWC in well 6407/9-1 was precluded by poor quality lithology at the base of sequence. A clearly defined oil-water contact at 1638.5 m MSL was however encountered in well 6407/9-2. The purpose of this fourth well was to evaluate the reservoir quality and sand development on the north-west flank of the accumulation, and to evaluate the oil deliverability and water injection potential of the reservoir sands.
    Operations and results
    Well 6407/9-4 was spudded with the semi-submersible installation West Venture on 4 July 1985 and drilled to TD at 1820 m in the Early Jurassic Tilje Formation. No significant problems were encountered while drilling the well. The well was drilled with seawater and bentonite down to 820 m, with KCl/polymer mud from 820 m to 1635 m, and with chalk mud from 1635 m to TD.
    Light oil with low gas content was discovered in the Garn Formation, as the Rogn Formation proved to be only 2 m thick. The oil/water contact was found at 1672 m (1639 m MSL), the same contact that had been established in previous wells on the Draugen Field. This indicated communication in the Rogn and Garn Formations between the wells drilled so far on Draugen. No oil shows were recorded above the reservoir. Below OWC oil shows continued down to 1681 m, otherwise no further oil shows were observed.
    Five cores were cut from 1666 m to 1711.5 m in the Fangst Group. An RFT segregated fluid sample was taken at 1664.5 m in the upper Garn Formation.
    The well was permanently abandoned on 10 September 1985 as an oil appraisal well.
    Testing
    To Drill Stem Tests were performed. One injection test at 1708 - 1713 m in the water zone, and one production test at 1662 -1667 m in the oil zone. Maximum injection rate in the water test was 2080 m3 /day. The oil test produced at maximum 998 Sm3 oil /day on a 64/64" choke. The GOR was ca 35 Sm3/Sm3, the oil density was 0.82, and the gas gravity was 0.82 (air = 1). Temperature measurements in the test gave a reservoir formation temperature of 71.1 deg C (160 deg F).

  • 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
    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
    1666.0
    1671.1
    [m ]
    2
    1673.0
    1674.7
    [m ]
    3
    1676.3
    1684.0
    [m ]
    4
    1685.7
    1695.0
    [m ]
    5
    1695.5
    1711.0
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    39.4
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 1666-1671m
    Core photo at depth: 1671-1671m
    Core photo at depth: 1673-1674m
    Core photo at depth: 1676-1681m
    Core photo at depth: 1681-1684m
    1666-1671m
    1671-1671m
    1673-1674m
    1676-1681m
    1681-1684m
    Core photo at depth: 1685-1690m
    Core photo at depth: 1690-1695m
    Core photo at depth: 1695-1700m
    Core photo at depth: 1700-1705m
    Core photo at depth: 1705-1710m
    1685-1690m
    1690-1695m
    1695-1700m
    1700-1705m
    1705-1710m
    Core photo at depth: 1710-1711m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    1710-1711m

  • 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
    TEST2A
    1662.00
    1667.00
    16.08.1985 - 23:30
    YES

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.36

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.14
    pdf
    1.19
    pdf
    0.37

  • 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
    17.79
    pdf
    1.01

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    1708
    1713
    0.0
    2.0
    1662
    1668
    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
    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
    962
    0.820
    0.820
    36

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL
    1590
    1710
    CBL VDL
    700
    1620
    CST GR
    1258
    1753
    ISF LSS GR
    365
    816
    ISF LSS GR
    805
    1626
    ISF LSS GR
    1622
    1816
    LDL CNL GR
    365
    818
    LDL CNL GR
    805
    1628
    LDL CNL NGS
    1622
    1817
    MSFL DLL GR
    1622
    1813
    RFT
    1664
    1664
    SHDT
    1622
    1815
    SWC
    1666
    1710
    VSP
    365
    1818

  • 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
    365.5
    36
    375.0
    0.00
    LOT
    SURF.COND.
    20
    804.5
    26
    820.0
    1.55
    LOT
    SURF.COND.
    20
    805.5
    26
    820.0
    1.55
    LOT
    INTERM.
    13 3/8
    1622.0
    17 1/2
    1635.0
    1.81
    LOT
    INTERM.
    9 5/8
    1793.0
    12 1/4
    1820.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    295
    1.03
    WATER BASED
    05.07.1985
    375
    1.03
    WATER BASED
    09.07.1985
    375
    0.00
    WATER BASED
    10.07.1985
    417
    1.06
    11.0
    59.0
    WATER BASED
    10.07.1985
    506
    1.20
    WATER BASED
    06.09.1985
    745
    1.06
    41.0
    16.0
    WATER BASED
    12.07.1985
    820
    1.09
    50.0
    26.0
    WATER BASED
    12.07.1985
    820
    1.10
    120.0
    WATER BASED
    15.07.1985
    820
    1.03
    WATER BASED
    15.07.1985
    820
    1.30
    WATER BASED
    18.07.1985
    820
    1.03
    WATER BASED
    15.07.1985
    820
    1.03
    WATER BASED
    16.07.1985
    820
    1.03
    WATER BASED
    16.07.1985
    820
    0.00
    WATER BASED
    18.07.1985
    820
    1.10
    120.0
    WATER BASED
    15.07.1985
    820
    1.30
    WATER BASED
    18.07.1985
    1000
    1.35
    43.0
    21.0
    WATER BASED
    19.07.1985
    1010
    1.20
    WATER BASED
    05.09.1985
    1076
    1.36
    53.0
    24.0
    water based
    22.07.1985
    1076
    1.36
    53.0
    24.0
    WATER BASED
    22.07.1985
    1084
    1.38
    53.0
    4.0
    WATER BASED
    22.07.1985
    1408
    1.40
    50.0
    5.0
    WATER BASED
    22.07.1985
    1470
    1.20
    WATER BASED
    04.09.1985
    1477
    1.15
    WATER BASED
    03.09.1985
    1510
    1.40
    47.0
    5.0
    WATER BASED
    23.07.1985
    1635
    1.20
    WATER BASED
    02.08.1985
    1635
    1.40
    50.0
    3.0
    WATER BASED
    25.07.1985
    1635
    1.40
    50.0
    3.0
    WATER BASED
    23.07.1985
    1635
    1.40
    50.0
    3.0
    WATER BASED
    25.07.1985
    1635
    1.40
    50.0
    3.0
    WATER BASED
    26.07.1985
    1635
    1.40
    50.0
    3.0
    WATER BASED
    26.07.1985
    1635
    1.20
    WATER BASED
    02.08.1985
    1635
    1.15
    WATER BASED
    20.08.1985
    1666
    1.19
    15.0
    20.0
    WATER BASED
    29.07.1985
    1673
    1.15
    WATER BASED
    20.08.1985
    1676
    1.19
    15.0
    18.0
    WATER BASED
    29.07.1985
    1683
    1.15
    WATER BASED
    20.08.1985
    1683
    1.15
    WATER BASED
    21.08.1985
    1683
    1.15
    WATER BASED
    21.08.1985
    1683
    1.15
    WATER BASED
    22.08.1985
    1683
    1.15
    WATER BASED
    23.08.1985
    1683
    1.15
    WATER BASED
    26.08.1985
    1683
    1.15
    WATER BASED
    27.08.1985
    1683
    1.15
    WATER BASED
    28.08.1985
    1683
    1.15
    WATER BASED
    29.08.1985
    1683
    1.15
    WATER BASED
    30.08.1985
    1683
    1.15
    WATER BASED
    02.09.1985
    1700
    1.20
    45.0
    4.0
    WATER BASED
    31.07.1985
    1755
    1.15
    WATER BASED
    19.08.1985
    1755
    1.15
    WATER BASED
    20.08.1985
    1755
    1.15
    WATER BASED
    19.08.1985
    1755
    1.15
    WATER BASED
    09.08.1985
    1793
    1.13
    WATER BASED
    09.08.1985
    1820
    1.20
    15.0
    19.0
    WATER BASED
    02.08.1985
    1820
    1.20
    17.0
    23.0
    WATER BASED
    05.08.1985
    1820
    1.20
    WATER BASED
    05.08.1985
    1820
    1.15
    WATER BASED
    09.08.1985
    1820
    1.20
    44.0
    4.0
    WATER BASED
    31.07.1985
    1820
    1.20
    15.0
    19.0
    WATER BASED
    02.08.1985
    1820
    1.20
    17.0
    23.0
    WATER BASED
    05.08.1985
    1820
    1.20
    WATER BASED
    05.08.1985
    1820
    1.15
    WATER BASED
    09.08.1985

  • Thin sections at the Norwegian Offshore Directorate
    Thin sections at the Norwegian Offshore Directorate
    Depth
    Unit
    1674.00
    [m ]
    1680.00
    [m ]
    1681.00
    [m ]
    1688.00
    [m ]
    1688.00
    [m ]
    1688.00
    [m ]
    1691.00
    [m ]
    1691.00
    [m ]
    1691.00
    [m ]
    1692.00
    [m ]
    1692.00
    [m ]
    1692.00
    [m ]
    1692.00
    [m ]

  • 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