Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
27.04.2024 - 01:34
Time of last synchronization with Norwegian Offshore Directorate's internal systems

6407/11-1

Export: PDF icon PDF

  • General information
    General information
    Attribute Value
    Wellbore name
    Official name of wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    6407/11-1
    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
    Press release
    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.
    6407/11-1
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    3D survey: PGS14005 Nearest Inline: 6677. Nearest X-line 4457
    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.
    Equinor Energy AS
    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.
    1727-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.
    21
    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,
    17.11.2018
    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.
    07.12.2018
    Plugged and abondon date
    Date when the P&A-operations of the wellbore was finished, as reported by the operator to the Norwegian Offshore Directorate throught DDRS (Daily Drilling Reporting System). Only applied once pr. wellhead/surface location.
    07.12.2018
    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.
    13.01.2020
    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.
    17.01.2020
    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.
    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.
    23.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    314.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2175.0
    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).
    2175.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    0.81
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    87
    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.
    ÅRE FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    64° 12' 22.82'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    7° 29' 33.28'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7121050.51
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    426814.42
    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.
    8565

  • Wellbore history
    General
    Well 6407/11-1 was drilled to test the Gunnvald prospect in the Froan Basin south-east of the Njord Field and south-west of the Draugen Field in the Norwegian Sea. The primary objective was to test migration of hydrocarbons into the Froan Basin, targeting the Tofte Formation as primary objective, and the Tilje Formation (Heidi prospect) as secondary
    Operations and results
    Wildcat well 6407/11-1 was spudded with the semi-submersible installation Deepsea Bergen on 17 November 2018 and drilled to TD at 2175 m in the Early Jurassic Åre Formation. Operations proceeded without significant problems. The well was drilled with seawater and hi-vis pills down to 967 m and with water-based KCl/GEM/Polymer mud from 967 m to TD.
    The well penetrated top Spekk Formation at 1743 m overlying the Rogn Formation from 1771 to 1774 m. The Rogn Formation lie unconformably on the Tofte Formation at 1774 m, while top Tilje Formation came in at 1937 m. The Tofte Formation is 110 m thick with ca 75 metres effective reservoir sandstone of good to very good reservoir quality. The Tilje Formation is 105 m thick with ca 47 m of effective reservoir sandstone of mainly good to very good reservoir quality. All reservoir sections were water wet. Gas levels were generally low throughout the well and there were no petroleum odour. A weak oil show was noted on core #2 at 1771 m in the Rogn Formation: no petroleum odour, no oil stain, spotted, moderate, yellow direct fluorescence, slow cloudy white cut, bluish white residual ring. No visible residue was observed.
    The interval from 1753 to 1787 m was cored in two cores. The cored section includes Spekk hot shale, Rogn sandstone and Tofte sandstone. Core recovery was 100% and 98% in cores #1 and #2, respectively. Core-log depth shift is +0.4 m for bot cores.  No fluid sample was taken.
    The well was permanently abandoned on 7 December 2018 as a dry well.
    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]
    970.00
    2176.00

  • 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
    1753.0
    1760.0
    [m ]
    2
    1760.0
    1786.5
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    33.5
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    980.0
    [m]
    DC
    APT
    1000.0
    [m]
    DC
    APT
    1020.0
    [m]
    DC
    APT
    1040.0
    [m]
    DC
    APT
    1060.0
    [m]
    DC
    APT
    1080.0
    [m]
    DC
    APT
    1100.0
    [m]
    DC
    APT
    1120.0
    [m]
    DC
    APT
    1140.0
    [m]
    DC
    APT
    1160.0
    [m]
    DC
    APT
    1180.0
    [m]
    DC
    APT
    1200.0
    [m]
    DC
    APT
    1220.0
    [m]
    DC
    APT
    1240.0
    [m]
    DC
    APT
    1260.0
    [m]
    DC
    APT
    1280.0
    [m]
    DC
    APT
    1300.0
    [m]
    DC
    APT
    1320.0
    [m]
    DC
    APT
    1340.0
    [m]
    DC
    APT
    1350.0
    [m]
    DC
    APT
    1360.0
    [m]
    DC
    APT
    1370.0
    [m]
    DC
    APT
    1380.0
    [m]
    DC
    APT
    1390.0
    [m]
    DC
    APT
    1400.0
    [m]
    DC
    APT
    1410.0
    [m]
    DC
    APT
    1420.0
    [m]
    DC
    APT
    1430.0
    [m]
    DC
    APT
    1440.0
    [m]
    DC
    APT
    1450.0
    [m]
    DC
    APT
    1460.0
    [m]
    DC
    APT
    1470.0
    [m]
    DC
    APT
    1480.0
    [m]
    DC
    APT
    1490.0
    [m]
    DC
    APT
    1500.0
    [m]
    DC
    APT
    1510.0
    [m]
    DC
    APT
    1520.0
    [m]
    DC
    APT
    1530.0
    [m]
    DC
    APT
    1540.0
    [m]
    DC
    APT
    1550.0
    [m]
    DC
    APT
    1560.0
    [m]
    DC
    APT
    1570.0
    [m]
    DC
    APT
    1580.0
    [m]
    DC
    APT
    1590.0
    [m]
    DC
    APT
    1600.0
    [m]
    DC
    APT
    1610.0
    [m]
    DC
    APT
    1620.0
    [m]
    DC
    APT
    1630.0
    [m]
    DC
    APT
    1640.0
    [m]
    DC
    APT
    1650.0
    [m]
    DC
    APT
    1660.0
    [m]
    DC
    APT
    1670.0
    [m]
    DC
    APT
    1680.0
    [m]
    DC
    APT
    1690.0
    [m]
    DC
    APT
    1700.0
    [m]
    DC
    APT
    1710.0
    [m]
    DC
    APT
    1720.0
    [m]
    DC
    APT
    1729.0
    [m]
    DC
    APT
    1735.0
    [m]
    DC
    APT
    1738.0
    [m]
    DC
    APT
    1741.0
    [m]
    DC
    APT
    1747.0
    [m]
    DC
    APT
    1750.0
    [m]
    DC
    APT
    1753.0
    [m]
    DC
    APT
    1753.4
    [m]
    C
    APT
    1754.4
    [m]
    C
    APT
    1755.9
    [m]
    C
    APT
    1756.0
    [m]
    DC
    APT
    1759.2
    [m]
    C
    APT
    1760.2
    [m]
    C
    APT
    1761.7
    [m]
    C
    APT
    1762.7
    [m]
    C
    APT
    1763.7
    [m]
    C
    APT
    1764.7
    [m]
    C
    APT
    1765.7
    [m]
    C
    APT
    1766.7
    [m]
    C
    APT
    1767.7
    [m]
    C
    APT
    1768.7
    [m]
    C
    APT
    1769.2
    [m]
    C
    APT
    1770.7
    [m]
    C
    APT
    1771.8
    [m]
    C
    APT
    1772.7
    [m]
    C
    APT
    1773.8
    [m]
    C
    APT
    1778.6
    [m]
    C
    APT
    1779.4
    [m]
    C
    APT
    1780.4
    [m]
    C
    APT
    1781.2
    [m]
    C
    APT
    1781.8
    [m]
    C
    APT
    1782.2
    [m]
    C
    APT
    1782.9
    [m]
    C
    APT
    1786.3
    [m]
    C
    APT
    1795.0
    [m]
    DC
    APT
    1804.0
    [m]
    DC
    APT
    1813.0
    [m]
    DC
    APT
    1822.0
    [m]
    DC
    APT
    1825.0
    [m]
    SWC
    APT
    1831.0
    [m]
    DC
    APT
    1843.0
    [m]
    DC
    APT
    1852.0
    [m]
    DC
    APT
    1861.0
    [m]
    DC
    APT
    1868.0
    [m]
    SWC
    APT
    1876.0
    [m]
    DC
    APT
    1888.0
    [m]
    DC
    APT
    1897.0
    [m]
    DC
    APT
    1906.0
    [m]
    DC
    APT
    1915.0
    [m]
    DC
    APT
    1924.0
    [m]
    DC
    APT
    1933.0
    [m]
    DC
    APT
    1945.0
    [m]
    DC
    APT
    1947.0
    [m]
    SWC
    APT
    1949.2
    [m]
    SWC
    APT
    1954.0
    [m]
    DC
    APT
    1955.0
    [m]
    SWC
    APT
    1963.0
    [m]
    DC
    APT
    1972.0
    [m]
    DC
    APT
    1981.0
    [m]
    DC
    APT
    1990.0
    [m]
    DC
    APT
    1999.0
    [m]
    DC
    APT
    2008.0
    [m]
    DC
    APT
    2017.0
    [m]
    DC
    APT
    2026.0
    [m]
    DC
    APT
    2038.0
    [m]
    DC
    APT
    2047.0
    [m]
    DC
    APT
    2056.0
    [m]
    DC
    APT
    2065.0
    [m]
    DC
    APT
    2074.0
    [m]
    DC
    APT
    2083.0
    [m]
    DC
    APT
    2092.0
    [m]
    DC
    APT
    2101.0
    [m]
    DC
    APT
    2110.0
    [m]
    DC
    APT
    2119.0
    [m]
    DC
    APT
    2128.0
    [m]
    DC
    APT
    2137.0
    [m]
    DC
    APT
    2146.0
    [m]
    DC
    APT
    2155.0
    [m]
    DC
    APT
    2164.0
    [m]
    DC
    APT
    2176.0
    [m]
    DC
    APT

  • Lithostratigraphy

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    GR RES DEN NEU
    1664
    2175
    MWD LWD - GR RES
    337
    2175
    RT SCANNER
    1664
    2175
    XL ROCK
    1664
    2175
    XL ROCK
    2000
    2175

  • 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
    382.0
    36
    382.0
    0.00
    INTERM.
    13 3/8
    961.0
    17 1/2
    967.0
    1.58
    FIT
    INTERM.
    9 5/8
    1663.9
    12 1/4
    1665.0
    1.53
    FIT
    OPEN HOLE
    2175.0
    8 1/2
    2175.0
    0.00

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    700
    1.39
    17.0
    KCl/Polymer/GEM
    967
    1.35
    16.0
    KCl/Polymer/GEM
    1420
    1.37
    17.0
    KCl/Polymer/GEM
    1666
    1.35
    18.0
    KCl/Polymer/GEM
    1666
    1.20
    12.0
    KCl/Polymer/GEM
    1769
    1.21
    11.0
    KCl/Polymer/GEM
    1905
    1.20
    13.0
    KCl/Polymer/GEM
    1973
    1.21
    11.0
    KCl/Polymer/GEM
    2175
    1.39
    15.0
    KCl/Polymer/GEM
    2175
    1.22
    10.0
    KCl/Polymer/GEM