Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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26.12.2024 - 01:26
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6407/12-1

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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.
    6407/12-1
    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).
    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.
    6407/12-1
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    SH 9002- INLINE 414 & X-LINE 412
    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.
    958-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.
    9
    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,
    07.07.1999
    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.
    15.07.1999
    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.
    15.07.2001
    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.
    29.05.2002
    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.
    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.
    23.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    289.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    1805.0
    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).
    1802.9
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    2.1
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    69
    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.
    GARN FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    64° 14' 23.44'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    7° 42' 7.98'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7124559.46
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    437067.41
    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.
    3781

  • Wellbore history
    General
    Exploration well 6407/12-1 is located on the western edge of the Trøndelag Platform in PL176, some 13 km South of the Draugen platform. It was drilled to test the hydrocarbon potential of the Upper Jurassic sands of the Rogn Formation, which is the main reservoir unit in the Draugen Field. The second objective was to log and sample the upper 20 m of the Middle Jurassic Garn Formation.
    Operations and results
    The well was spudded on 7 July 1999 with the semi-submersible installation "Mærsk Jutlander" and drilled to a total depth of 1805 m in sandstone of the Garn Formation. It was drilled with sea water and Hi-vis bentonite pills to 714 m and with BARASILC silicate mud from 714 m to TD. The well found 2.3 m of oil-bearing sands in good quality reservoirs of the Rogn Formation. The Rogn Formation in the well is in pressure communication with the Rogn Formation reservoir of the Draugen Field. An oil MDT sample was acquired from 1660.7 m in the Rogn Formation. Sampling occurred extremely slowly despite a recorded mobility of 249 md/cp and a high porosity indicated from the density log. This suggests potential plugging of the probe due to the unconsolidated nature of the Rogn sandstone. The Garn Formation came in at 1763 m. No conventional core was cut in the well. The well was plugged and abandoned on 15 July 1999.
    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
    1805.00

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    970.0
    [m]
    DC
    RRI
    990.0
    [m]
    DC
    RRI
    1010.0
    [m]
    DC
    RRI
    1030.0
    [m]
    DC
    RRI
    1050.0
    [m]
    DC
    RRI
    1070.0
    [m]
    DC
    RRI
    1080.0
    [m]
    DC
    RRI
    1100.0
    [m]
    DC
    RRI
    1120.0
    [m]
    DC
    RRI
    1140.0
    [m]
    DC
    RRI
    1160.0
    [m]
    DC
    RRI
    1180.0
    [m]
    DC
    RRI
    1190.0
    [m]
    DC
    RRI
    1210.0
    [m]
    DC
    RRI
    1210.0
    [m]
    DC
    FUGRO
    1230.0
    [m]
    DC
    FUGRO
    1230.0
    [m]
    DC
    RRI
    1240.0
    [m]
    DC
    RRI
    1240.0
    [m]
    DC
    FUGRO
    1260.0
    [m]
    DC
    FUGRO
    1260.0
    [m]
    DC
    RRI
    1280.0
    [m]
    DC
    RRI
    1280.0
    [m]
    DC
    FUGRO
    1290.0
    [m]
    DC
    FUGRO
    1300.0
    [m]
    DC
    FUGRO
    1300.0
    [m]
    DC
    RRI
    1305.0
    [m]
    DC
    FUGRO
    1310.0
    [m]
    DC
    FUGRO
    1315.0
    [m]
    DC
    RRI
    1320.0
    [m]
    DC
    FUGRO
    1330.0
    [m]
    DC
    RRI
    1340.0
    [m]
    DC
    FUGRO
    1350.0
    [m]
    DC
    RRI
    1360.0
    [m]
    DC
    FUGRO
    1370.0
    [m]
    DC
    RRI
    1380.0
    [m]
    DC
    FUGRO
    1390.0
    [m]
    DC
    RRI
    1400.0
    [m]
    DC
    FUGRO
    1410.0
    [m]
    DC
    RRI
    1420.0
    [m]
    DC
    FUGRO
    1430.0
    [m]
    DC
    RRI
    1440.0
    [m]
    DC
    FUGRO
    1450.0
    [m]
    DC
    RRI
    1460.0
    [m]
    DC
    FUGRO
    1470.0
    [m]
    DC
    RRI
    1490.0
    [m]
    DC
    RRI
    1509.0
    [m]
    DC
    RRI
    1527.0
    [m]
    DC
    RRI
    1539.0
    [m]
    DC
    RRI
    1548.0
    [m]
    DC
    RRI
    1563.0
    [m]
    DC
    RRI
    1578.0
    [m]
    DC
    RRI
    1584.0
    [m]
    DC
    RRI
    1587.0
    [m]
    DC
    RRI
    1590.0
    [m]
    DC
    RRI
    1596.0
    [m]
    DC
    RRI
    1611.0
    [m]
    DC
    RRI
    1617.0
    [m]
    DC
    RRI
    1620.0
    [m]
    SWC
    RRI
    1622.0
    [m]
    SWC
    RRI
    1623.0
    [m]
    DC
    PETROSTR
    1632.0
    [m]
    DC
    PETROS
    1632.0
    [m]
    DC
    RRI
    1635.0
    [m]
    DC
    RRI
    1635.0
    [m]
    SWC
    RRI
    1645.0
    [m]
    SWC
    RRI
    1647.0
    [m]
    DC
    RRI
    1647.0
    [m]
    DC
    PETROSTR
    1655.0
    [m]
    SWC
    RRI
    1656.0
    [m]
    DC
    RRI
    1660.0
    [m]
    SWC
    RRI
    1661.0
    [m]
    SWC
    RRI
    1662.0
    [m]
    SWC
    RRI
    1662.0
    [m]
    DC
    PETROSTR
    1665.0
    [m]
    SWC
    RRI
    1668.0
    [m]
    SWC
    RRI
    1672.5
    [m]
    SWC
    RRI
    1679.0
    [m]
    SWC
    RRI
    1680.0
    [m]
    DC
    PETROSTR
    1688.0
    [m]
    SWC
    RRI
    1689.0
    [m]
    DC
    PETROSTR
    1700.0
    [m]
    SWC
    RRI
    1707.0
    [m]
    DC
    RRI
    1707.0
    [m]
    DC
    PETROSTR
    1715.0
    [m]
    SWC
    RRI
    1719.0
    [m]
    DC
    PETROSTR
    1722.5
    [m]
    DC
    RRI
    1725.0
    [m]
    DC
    PETROS
    1725.0
    [m]
    DC
    RRI
    1725.0
    [m]
    SWC
    RRI
    1730.5
    [m]
    SWC
    RRI
    1731.0
    [m]
    DC
    RRI
    1731.0
    [m]
    DC
    PETROSTR
    1740.0
    [m]
    DC
    RRI
    1746.0
    [m]
    DC
    RRI
    1752.0
    [m]
    DC
    RRI
    1758.0
    [m]
    DC
    RRI
    1761.0
    [m]
    DC
    RRI
    1761.0
    [m]
    DC
    PETROSTR
    1768.5
    [m]
    SWC
    RRI
    1776.0
    [m]
    DC
    RRI
    1782.0
    [m]
    DC
    RRI
    1785.0
    [m]
    DC
    RRI
    1791.0
    [m]
    DC
    RRI
    1797.0
    [m]
    DC
    RRI
    1805.0
    [m]
    DC
    RRI

  • Lithostratigraphy
    Lithostratigraphy
    Top depth [mMD RKB]
    Lithostrat. unit
    314
    1282
    1282
    1412
    1542
    1542
    1579
    1591
    1591
    1614
    1625
    1625
    1659
    1721
    1731
    1763
    1763

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.13

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.92

  • 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
    1.46
    .pdf
    44.13

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CST
    1580
    1768
    MDT
    1660
    1771
    MWD LWD DIR
    311
    1805
    PEX/DSI HALS MCFL TLD HNGS
    1558
    1802
    VSP
    400
    1800

  • 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
    373.0
    36
    375.0
    0.00
    LOT
    INTERM.
    9 5/8
    1805.0
    12 1/4
    1805.0
    1.85
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    963
    1.20
    9.0
    SPUD MUD
    1805
    1.35
    26.0
    BARASILC
    1805
    1.35
    26.0
    BARASILC

  • 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
    0.23