Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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25.11.2024 - 01:30
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6407/9-1

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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.
    6407/9-1
    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
    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.
    6407/9-1
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    729 - 408 SP. 390
    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.
    422-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.
    74
    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,
    26.06.1984
    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.
    07.09.1984
    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.
    07.09.1986
    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.
    WILDCAT
    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.
    YES
    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.
    248.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2500.0
    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).
    2500.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    2
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    99
    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.
    LATE TRIASSIC
    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.
    RED BEDS (INFORMAL)
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    64° 21' 56.14'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    7° 47' 20.86'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7138488.30
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    441548.41
    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.
    133

  • Wellbore history
    General
    Wildcat well 6407/9-1 was drilled in the Froan Basin offshore Mid Norway. The primary objective of the well was evaluation of possible reservoirs of Early to Middle Jurassic age. Secondary objectives were evaluation of deeper reservoirs of Early Jurassic to Upper Triassic age.
    The well is Type Well for the Rogn Formation. It is Reference well for the Viking Group and Spekk Formation
    Operations and results
    Wildcat well 6407/9-1 was spudded with the semi-submersible installation Borgny Dolphin on 26 June 1984 and drilled to TD at 2500 m in the Late Triassic Red Beds. Due to high deviation in the 36" hole section, the well was re-spudded. Junk was fished out of the hole before and after performing a leak off test below the 20" casing shoe. Gas bubbles were observed around the BOP stack, the 20" casing was perforated and several cement squeeze jobs were performed. The 13 3/8" casing was run just below the 20" casing. Some technical problems occurred while drilling the 12 1/4" hole. Some tight spots occurred in the two lowermost hole sections. The bottom hole assembly got stuck at 2027 m, but was successfully freed. The well was drilled with seawater and bentonite down to 809 m and with KCl/Polymer mud from 809 m to TD.
    The well encountered a Late Jurassic intra-Spekk Formation sandstone unit which was previously unknown in the Haltenbanken area. It has later formally been named the Rogn Formation. It was oil filled from the top at 1621 m down to an OWC at 1660 m. Tests showed light oil with a low content of gas and condensate. The underlying reservoir sandstones of Middle/Early Jurassic to Late Triassic age were all water bearing, nor were oil shows reported in any other porous section in the well. Five cores were cut from the Late Jurassic into the Middle Jurassic. The three first were cut in the Rogn Formation while the two last recovered an underlying Spekk sequence and upper part of the Garn Formation. RFT oil and water samples were successfully recovered from 1635 m and 1703 m, respectively.
    The well was permanently abandoned on 7 September 1984 as an oil discovery.
    Testing
    One production test was carried out the in the interval 1632 m to 1638 m in the Rogn Formation. A maximum flow rate of 1351 Sm3/day (8500 BOPD) through a 2" choke was sustained for two days. The GOR was 38 Sm2/Sm3 (211 scf/STB), oil gravity was 40 deg API, and separator gas gravity was 0.89 (air = 1). The CO2 content was 1%, no H2S was detected. Bottom hole temperature recorded during the test was 68.3 deg C (155 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]
    410.00
    2500.00

  • 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
    1631.0
    1643.2
    [m ]
    2
    1645.0
    1661.4
    [m ]
    3
    1663.0
    1670.0
    [m ]
    4
    1670.0
    1673.9
    [m ]
    5
    1674.0
    1683.0
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    48.5
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 1631-1637m
    Core photo at depth: 1637-1643m
    Core photo at depth: 1643-1644m
    Core photo at depth: 1645-1651m
    Core photo at depth: 1651-1657m
    1631-1637m
    1637-1643m
    1643-1644m
    1645-1651m
    1651-1657m
    Core photo at depth: 1657-1661m
    Core photo at depth: 1663-1669m
    Core photo at depth: 1669-1670m
    Core photo at depth: 1670-1674m
    Core photo at depth: 1674-1680m
    1657-1661m
    1663-1669m
    1669-1670m
    1670-1674m
    1674-1680m
    Core photo at depth: 1680-1683m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    1680-1683m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    750.0
    [m]
    DC
    OD
    760.0
    [m]
    DC
    OD
    770.0
    [m]
    DC
    OD
    780.0
    [m]
    DC
    OD
    790.0
    [m]
    DC
    OD
    820.0
    [m]
    DC
    OD
    830.0
    [m]
    DC
    OD
    840.0
    [m]
    DC
    OD
    850.0
    [m]
    DC
    OD
    1666.8
    [m]
    C
    1670.0
    [m]
    C
    1671.7
    [m]
    C
    1674.3
    [m]
    C
    1675.0
    [m]
    C
    1676.3
    [m]
    C
    1756.0
    [m]
    DC
    OD
    1762.0
    [m]
    DC
    OD
    1777.0
    [m]
    DC
    OD
    1792.0
    [m]
    DC
    OD
    1807.0
    [m]
    DC
    OD
    1822.0
    [m]
    DC
    OD
    1837.0
    [m]
    DC
    OD
    1852.0
    [m]
    DC
    OD
    1867.0
    [m]
    DC
    OD
    1882.0
    [m]
    DC
    OD
    1897.0
    [m]
    DC
    OD
    1912.0
    [m]
    DC
    OD
    1927.0
    [m]
    DC
    OD
    1942.0
    [m]
    DC
    OD
    1957.0
    [m]
    DC
    OD
    1972.0
    [m]
    DC
    OD
    1987.0
    [m]
    DC
    OD
    2002.0
    [m]
    DC
    OD
    2017.0
    [m]
    DC
    OD
    2032.0
    [m]
    DC
    OD
    2047.0
    [m]
    DC
    OD
    2062.0
    [m]
    DC
    OD
    2077.0
    [m]
    DC
    OD
    2092.0
    [m]
    DC
    OD
    2107.0
    [m]
    DC
    OD
    2122.0
    [m]
    DC
    OD
    2137.0
    [m]
    DC
    OD
    2152.0
    [m]
    DC
    OD
    2167.0
    [m]
    DC
    OD
    2182.0
    [m]
    DC
    OD
    2197.0
    [m]
    DC
    OD
    2212.0
    [m]
    DC
    OD
    2227.0
    [m]
    DC
    OD
    2242.0
    [m]
    DC
    OD
    2257.0
    [m]
    DC
    OD
    2272.0
    [m]
    DC
    OD
    2287.0
    [m]
    DC
    OD
    2305.0
    [m]
    DC
    OD
    2320.0
    [m]
    DC
    OD
    2335.0
    [m]
    DC
    OD
    2350.0
    [m]
    DC
    OD
    2362.0
    [m]
    DC
    OD
    2377.0
    [m]
    DC
    OD
    2395.0
    [m]
    DC
    OD
    2410.0
    [m]
    DC
    OD
    2425.0
    [m]
    DC
    OD
    2440.0
    [m]
    DC
    OD
    2455.0
    [m]
    DC
    OD
    2470.0
    [m]
    DC
    OD

  • 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
    1638.00
    1632.00
    29.08.1984 - 15:00
    YES
    DST
    TEST1
    1632.00
    1638.00
    29.08.1984 - 15:00
    YES

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.49

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.81
    pdf
    1.15
    pdf
    0.85
    pdf
    0.41

  • Documents – reported by the production licence (period for duty of secrecy expired)

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    1632
    1638
    48.0
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    68
    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
    1351
    51338
    0.820
    0.890
    38

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    DLL MSFL GR
    1612
    1800
    HDT
    1612
    2485
    ISF LSS GR
    273
    807
    ISF LSS GR
    827
    1597
    ISF LSS GR
    1597
    1611
    ISF LSS GR
    1613
    2487
    LDL CNL GR
    382
    809
    LDL CNL GR
    830
    1611
    LDL CNL NGT
    1613
    2489
    RFT
    1599
    2373
    SWS
    840
    2500
    VELOCITY
    675
    2485

  • 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
    383.0
    36
    395.0
    0.00
    LOT
    SURF.COND.
    20
    799.0
    26
    811.0
    1.39
    LOT
    INTERM.
    13 3/8
    830.0
    17 1/2
    840.0
    1.42
    LOT
    INTERM.
    9 5/8
    1616.0
    12 1/4
    1630.0
    1.64
    LOT
    LINER
    7
    2484.0
    8 1/2
    2500.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    811
    1.03
    WATER BASED
    06.07.1984
    818
    1.02
    19.0
    26.0
    WATER BASED
    10.07.1984
    818
    1.03
    WATER BASED
    11.07.1984
    818
    1.03
    WATER BASED
    12.07.1984
    818
    1.03
    WATER BASED
    16.07.1984
    818
    1.03
    WATER BASED
    11.07.1984
    818
    1.03
    WATER BASED
    12.07.1984
    818
    1.03
    WATER BASED
    13.07.1984
    818
    1.03
    WATER BASED
    16.07.1984
    818
    1.03
    WATER BASED
    13.07.1984
    840
    1.11
    15.0
    17.0
    WATER BASED
    16.07.1984
    840
    1.11
    15.0
    17.0
    WATER BASED
    16.07.1984
    840
    1.10
    18.0
    20.0
    WATER BASED
    16.07.1984
    980
    1.25
    17.0
    18.0
    WATER BASED
    17.07.1984
    1360
    1.30
    20.0
    20.0
    WATER BASED
    18.07.1984
    1560
    1.31
    20.0
    17.0
    WATER BASED
    20.07.1984
    1630
    1.33
    23.0
    21.0
    WATER BASED
    23.07.1984
    1630
    1.31
    24.0
    20.0
    WATER BASED
    25.07.1984
    1630
    1.34
    22.0
    19.0
    WATER BASED
    27.07.1984
    1630
    1.35
    23.0
    22.0
    WATER BASED
    20.07.1984
    1630
    1.35
    23.0
    22.0
    WATER BASED
    23.07.1984
    1630
    1.33
    24.0
    23.0
    WATER BASED
    23.07.1984
    1630
    1.33
    23.0
    21.0
    WATER BASED
    23.07.1984
    1630
    1.33
    22.0
    19.0
    WATER BASED
    24.07.1984
    1630
    1.31
    24.0
    20.0
    WATER BASED
    25.07.1984
    1630
    1.34
    20.0
    18.0
    WATER BASED
    26.07.1984
    1630
    1.34
    22.0
    19.0
    WATER BASED
    27.07.1984
    1630
    1.35
    23.0
    22.0
    WATER BASED
    23.07.1984
    1630
    1.33
    24.0
    23.0
    WATER BASED
    23.07.1984
    1630
    1.33
    22.0
    19.0
    WATER BASED
    24.07.1984
    1630
    1.34
    20.0
    18.0
    WATER BASED
    26.07.1984
    1632
    1.12
    WATER BASED
    21.08.1984
    1632
    1.12
    WATER BASED
    23.08.1984
    1632
    1.12
    WATER BASED
    27.08.1984
    1632
    1.12
    WATER BASED
    28.08.1984
    1632
    1.12
    WATER BASED
    30.08.1984
    1632
    1.12
    WATER BASED
    03.09.1984
    1632
    1.12
    WATER BASED
    23.08.1984
    1632
    1.12
    WATER BASED
    27.08.1984
    1632
    1.12
    WATER BASED
    28.08.1984
    1632
    1.12
    WATER BASED
    30.08.1984
    1632
    1.12
    WATER BASED
    31.08.1984
    1632
    1.12
    WATER BASED
    03.09.1984
    1632
    1.12
    WATER BASED
    31.08.1984
    1747
    1.33
    21.0
    20.0
    WATER BASED
    30.07.1984
    1831
    1.33
    21.0
    20.0
    WATER BASED
    30.07.1984
    1956
    1.33
    21.0
    18.0
    WATER BASED
    30.07.1984
    2069
    1.33
    21.0
    20.0
    WATER BASED
    30.07.1984
    2125
    1.33
    23.0
    21.0
    WATER BASED
    01.08.1984
    2256
    1.33
    22.0
    21.0
    WATER BASED
    01.08.1984
    2367
    1.34
    22.0
    22.0
    WATER BASED
    03.08.1984
    2465
    1.33
    20.0
    22.0
    WATER BASED
    06.08.1984
    2500
    1.33
    20.0
    21.0
    WATER BASED
    06.08.1984
    2500
    1.33
    21.0
    20.0
    WATER BASED
    07.08.1984
    2500
    1.33
    25.0
    20.0
    WATER BASED
    08.08.1984
    2500
    1.33
    20.0
    21.0
    WATER BASED
    06.08.1984
    2500
    1.33
    21.0
    20.0
    WATER BASED
    07.08.1984
    2500
    1.33
    25.0
    20.0
    WATER BASED
    08.08.1984
    2500
    1.33
    20.0
    21.0
    WATER BASED
    06.08.1984

  • 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
    0.29