Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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31.10.2024 - 01:27
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6408/4-1

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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.
    6408/4-1
    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
    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
    Well name
    Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    6408/4-1
    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.
    Conoco Norway Inc.
    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.
    586-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.
    31
    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,
    18.09.1988
    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.
    18.10.1988
    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.
    18.10.1990
    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.
    30.06.2005
    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
    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.
    DRY
    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
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    27.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    209.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2725.0
    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).
    2725.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    2.5
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    94
    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.
    GREY 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° 40' 0.22'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    8° 15' 27.05'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7171699.06
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    464550.03
    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.
    1246

  • Wellbore history
    General
    Block 6408/4 is situated on the eastern side of the Trøndelag Platform off shore mid Norway. The drilled prospect is a large, gently dipping structure that is bounded by a southeast dipping fault with dip closure in all other directions.
    The objectives were to test for the development of the Late Jurassic Rogn sands and their hydrocarbon potential, and to test for hydrocarbons in the Middle Jurassic Fangst sands. Both Late Jurassic shales and the Lower Jurassic Åre coal unit were considered to be immature on the block. Long distance migration of oil was a critical aspect of the prospect and as such constituted a major risk.
    Operations and results
    Wildcat well 6408/4-1 was spudded with the semi-submersible installation Vinni on 18 September 1988 and drilled to TD at 2725 m in the Triassic Grey Beds. There were certain problems with hole stability down to 830 m. The drill string twisted off at 370 m and had to be fished up. During logging the tool did not get past 622 m, and due to this there is a lack of conventional log between 622 - 830 m. Otherwise operations went without significant problems. The well was drilled with seawater and hi-vis pills down to 830 m and with KCl/polymer mud from 830 m to TD. No shallow gas was encountered.
    The prognosed sand in the Rogn Formation was not developed. A change from high gamma response shale to lower gamma response at 1734 m in the Spekk Formation was noted. The reservoir sections in the Middle and Early Jurassic Fangst Group were encountered at 1825 m to2015 m with 140 m net sand with 30.5% average porosity (log evaluation). The Båt group and the Triassic also had sands; the most massive of these was the Tilje Formation with 130 m net reservoir with 25.6% average porosity. All reservoir sections were water bearing and there were no shows or stain recorded while drilling. One core was cut between 1745 m to 1746.4 m in the Spekk Formation. A second core was attempted without success. No RFT was run in the well and no fluid sampling attempted.
    The well was permanently abandoned on 18 October 1988 as a dry hole.
    Testing
    No drill stem test was performed.

  • 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]
    840.00
    2725.00

  • 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
    1745.0
    1746.4
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    1.4
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    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
    340.0
    36
    346.0
    0.00
    LOT
    SURF.COND.
    20
    820.0
    26
    830.0
    1.53
    LOT
    INTERM.
    13 3/8
    1673.0
    17 1/2
    1692.0
    1.75
    LOT
    OPEN HOLE
    2725.0
    12 1/4
    2725.0
    0.00
    LOT

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL VDL
    240
    1673
    DIFL LSAC GR SP
    575
    1674
    DIFL LSAC GR SP
    1673
    2720
    DIFL LSAC GR SP CAL
    236
    616
    DIPLOG
    1673
    2721
    MWD RGD
    236
    2725
    SWC
    1679
    2638
    VELOCITY
    236
    2720
    VSP
    1000
    2708
    ZDEN CN GR CAL
    820
    1675
    ZDEN CN GR SPL CAL
    1673
    2713

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.31

  • 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
    9.87

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    260
    1.02
    WATER BASED
    19.09.1988
    346
    1.06
    WATER BASED
    20.09.1988
    346
    1.06
    WATER BASED
    21.09.1988
    415
    1.06
    WATER BASED
    22.09.1988
    830
    1.06
    WATER BASED
    23.09.1988
    830
    1.06
    WATER BASED
    26.09.1988
    830
    1.20
    WATER BASED
    26.09.1988
    830
    1.20
    WATER BASED
    26.09.1988
    830
    0.00
    WATER BASED
    27.09.1988
    830
    0.00
    WATER BASED
    28.09.1988
    859
    1.22
    WATER BASED
    29.09.1988
    1433
    1.36
    WATER BASED
    30.09.1988
    1692
    1.39
    25.0
    15.0
    WATER BASED
    03.10.1988
    1692
    1.40
    25.0
    15.0
    WATER BASED
    04.10.1988
    1692
    1.42
    26.0
    17.0
    WATER BASED
    05.10.1988
    1692
    1.38
    25.0
    15.0
    WATER BASED
    06.10.1988
    1711
    1.21
    15.0
    9.0
    WATER BASED
    07.10.1988
    1746
    1.20
    16.0
    12.5
    WATER BASED
    10.10.1988
    1938
    1.22
    14.0
    11.0
    WATER BASED
    10.10.1988
    2328
    1.23
    17.0
    13.5
    WATER BASED
    10.10.1988
    2471
    1.21
    15.0
    11.5
    WATER BASED
    11.10.1988
    2725
    1.25
    17.0
    13.0
    WATER BASED
    13.10.1988
    2725
    1.25
    17.0
    13.5
    WATER BASED
    14.10.1988
    2725
    1.21
    15.0
    11.0
    WATER BASED
    12.10.1988
    2725
    1.25
    17.0
    13.5
    WATER BASED
    17.10.1988

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1340.0
    [m]
    DC
    STRAT
    1370.0
    [m]
    DC
    STRAT
    1400.0
    [m]
    DC
    STRAT
    1430.0
    [m]
    DC
    STRAT
    1460.0
    [m]
    DC
    STRAT
    1480.0
    [m]
    DC
    STRAT
    1490.0
    [m]
    DC
    STRAT
    1500.0
    [m]
    DC
    STRAT
    1512.0
    [m]
    DC
    STRAT
    1526.0
    [m]
    DC
    STRAT
    1530.0
    [m]
    DC
    STRAT
    1542.0
    [m]
    DC
    STRAT
    1554.0
    [m]
    DC
    STRAT
    1560.0
    [m]
    DC
    STRAT
    1572.0
    [m]
    DC
    STRAT
    1584.0
    [m]
    DC
    STRAT
    1590.0
    [m]
    DC
    STRAT
    1602.0
    [m]
    DC
    STRAT
    1614.0
    [m]
    DC
    STRAT
    1620.0
    [m]
    DC
    STRAT
    1632.0
    [m]
    DC
    STRAT
    1644.0
    [m]
    DC
    STRAT
    1650.0
    [m]
    DC
    STRAT
    1662.0
    [m]
    DC
    STRAT
    1668.0
    [m]
    DC
    STRAT
    1674.0
    [m]
    DC
    STRAT
    1679.0
    [m]
    SWC
    STRAT
    1683.0
    [m]
    DC
    STRAT
    1693.0
    [m]
    DC
    STRAT
    1698.0
    [m]
    DC
    STRAT
    1703.0
    [m]
    SWC
    STRAT
    1704.0
    [m]
    DC
    STRAT
    1713.0
    [m]
    DC
    STRAT
    1720.0
    [m]
    DC
    STRAT
    1722.0
    [m]
    DC
    STRAT
    1734.0
    [m]
    DC
    STRAT
    1745.0
    [m]
    SWC
    STRAT
    1756.0
    [m]
    SWC
    STRAT
    1763.0
    [m]
    SWC
    STRAT
    1775.0
    [m]
    SWC
    STRAT
    1782.0
    [m]
    DC
    STRAT
    1792.0
    [m]
    SWC
    STRAT
    1795.0
    [m]
    SWC
    STRAT
    1800.0
    [m]
    SWC
    STRAT
    1812.0
    [m]
    SWC
    STRAT
    1822.0
    [m]
    SWC
    STRAT
    1825.0
    [m]
    SWC
    STRAT
    1839.0
    [m]
    DC
    STRAT
    1854.0
    [m]
    DC
    STRAT
    1863.0
    [m]
    DC
    STRAT
    1872.0
    [m]
    DC
    STRAT
    1878.0
    [m]
    SWC
    STRAT
    1882.0
    [m]
    SWC
    STRAT
    1888.0
    [m]
    SWC
    STRAT
    1896.0
    [m]
    DC
    STRAT
    1909.0
    [m]
    SWC
    STRAT
    1917.0
    [m]
    DC
    STRAT
    1924.0
    [m]
    SWC
    STRAT
    1932.0
    [m]
    SWC
    STRAT
    1944.0
    [m]
    DC
    STRAT
    1953.0
    [m]
    SWC
    STRAT
    1960.0
    [m]
    SWC
    STRAT
    1970.0
    [m]
    SWC
    STRAT
    1980.0
    [m]
    DC
    STRAT
    1989.0
    [m]
    DC
    STRAT
    1998.0
    [m]
    DC
    STRAT
    2007.0
    [m]
    DC
    STRAT
    2016.0
    [m]
    DC
    STRAT
    2025.0
    [m]
    DC
    STRAT
    2034.0
    [m]
    DC
    STRAT
    2042.0
    [m]
    SWC
    STRAT
    2052.0
    [m]
    DC
    STRAT
    2056.0
    [m]
    SWC
    STRAT
    2070.0
    [m]
    DC
    STRAT
    2075.0
    [m]
    SWC
    STRAT
    2088.0
    [m]
    DC
    STRAT
    2097.0
    [m]
    DC
    STRAT
    2106.0
    [m]
    DC
    STRAT
    2115.0
    [m]
    DC
    STRAT
    2127.0
    [m]
    DC
    STRAT
    2136.0
    [m]
    SWC
    STRAT
    2145.0
    [m]
    DC
    STRAT
    2157.0
    [m]
    SWC
    STRAT
    2163.0
    [m]
    DC
    STRAT
    2172.0
    [m]
    DC
    STRAT
    2181.0
    [m]
    DC
    STRAT
    2190.0
    [m]
    DC
    STRAT
    2199.0
    [m]
    DC
    STRAT
    2208.0
    [m]
    DC
    STRAT
    2217.0
    [m]
    DC
    STRAT
    2226.0
    [m]
    DC
    STRAT
    2235.0
    [m]
    DC
    STRAT
    2244.0
    [m]
    DC
    STRAT
    2253.0
    [m]
    SWC
    STRAT
    2262.0
    [m]
    DC
    STRAT
    2271.0
    [m]
    DC
    STRAT
    2280.0
    [m]
    DC
    STRAT
    2289.0
    [m]
    DC
    STRAT
    2298.0
    [m]
    DC
    STRAT
    2307.0
    [m]
    DC
    STRAT
    2312.0
    [m]
    SWC
    STRAT
    2316.0
    [m]
    DC
    STRAT
    2325.0
    [m]
    SWC
    STRAT
    2328.0
    [m]
    DC
    STRAT
    2334.0
    [m]
    DC
    STRAT
    2346.0
    [m]
    DC
    STRAT
    2357.0
    [m]
    SWC
    STRAT
    2373.0
    [m]
    DC
    STRAT
    2378.0
    [m]
    SWC
    STRAT
    2388.0
    [m]
    DC
    STRAT
    2400.0
    [m]
    DC
    STRAT
    2412.0
    [m]
    DC
    STRAT
    2424.0
    [m]
    DC
    STRAT
    2436.0
    [m]
    DC
    STRAT
    2448.0
    [m]
    DC
    STRAT
    2457.0
    [m]
    SWC
    STRAT
    2460.0
    [m]
    DC
    STRAT
    2472.0
    [m]
    DC
    STRAT
    2484.0
    [m]
    DC
    STRAT
    2496.0
    [m]
    DC
    STRAT
    2502.0
    [m]
    DC
    STRAT
    2517.0
    [m]
    DC
    STRAT
    2528.0
    [m]
    SWC
    STRAT
    2541.0
    [m]
    DC
    STRAT
    2553.0
    [m]
    DC
    STRAT
    2565.0
    [m]
    DC
    STRAT
    2577.0
    [m]
    DC
    STRAT
    2589.0
    [m]
    DC
    STRAT
    2602.0
    [m]
    SWC
    STRAT
    2613.0
    [m]
    DC
    STRAT
    2625.0
    [m]
    DC
    STRAT
    2638.0
    [m]
    SWC
    STRAT
    2656.0
    [m]
    DC
    STRAT
    2667.0
    [m]
    DC
    STRAT
    2679.0
    [m]
    DC
    STRAT
    2691.0
    [m]
    DC
    STRAT
    2703.0
    [m]
    DC
    STRAT
    2715.0
    [m]
    DC
    STRAT
    2725.0
    [m]
    DC
    STRAT