Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
21.11.2024 - 01:28
Time of last synchronization with Norwegian Offshore Directorate's internal systems

6507/6-3

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.
    6507/6-3
    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.
    6507/6-3
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    3D survey ST05M10-inline 2917 & x-line 3517
    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.
    StatoilHydro ASA
    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.
    1197-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.
    25
    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,
    31.10.2008
    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.
    24.11.2008
    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.
    24.11.2010
    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.
    24.11.2010
    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.
    26.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    400.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    1850.0
    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).
    1850.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    1.6
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    59
    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.
    65° 38' 58.4'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    7° 55' 37.6'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7281454.08
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    450637.36
    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.
    5922

  • Wellbore history
    General
    The 6507/6-3 Steinkobbe well is located on the east flank of the Nordland Ridge in the Norwegian Sea. The structure is a large rotated fault block and comprise of rock of Quaternary, Cretaceous and Jurassic age. The primary objective of the well was to prove commercial hydrocarbons in the Fangst and Båt Groups in the Steinkobbe prospect. A secondary objective was to test the presence and type of hydrocarbons in the Grytfoten lead in the Paleocene Tang-/Tare Formations.
    Operations and results
    Well 6507/6-3 was spudded with the semi-submersible installation Transocean Winner on 31 October 2008 and drilled to TD at 1850 m in Early Jurassic sediments of the Åre Formation. No shallow gas was observed by the ROV at the wellhead or by the MWD while drilling the 36" hole and the 17 1/2" hole. The well was drilled with Seawater and bentonite sweeps down to 479 m, with seawater, bentonite sweeps and Glydril from 479 m to 1000 m, and with Glydril mud from 1000 m to TD.
    The well penetrated rocks of Quaternary, Tertiary, Cretaceous, and Jurassic age. The Cretaceous was represented by 6 m Springar Formation only. The Viking Group consisted of 31 m Spekk Formation, of which the upper half was highly radioactive, and 59 m Melke Formation. Top Fangst was penetrated at 1430 m. From petrophysical analyses and cuttings descriptions the primary target Fangst an Båt reservoirs consisted of highly porous sandstones and clay rich sections with high porosity due to shallow burial depth and little compaction. No hydrocarbons were found and no shows were recorded in the well.
    No cores were cut. The MDT was run on wire line to establish pressure gradients and take fluid samples. A water gradient was established, and water was sampled in the Ile Formation at a depth of 1438.0 m.
    The well was permanently abandoned on 24 November 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]
    1010.00
    1850.00

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1020.0
    [m]
    DC
    BIOSTRAT
    1040.0
    [m]
    DC
    BIOSTR
    1060.0
    [m]
    DC
    BIOSTR
    1080.0
    [m]
    DC
    BIOSTR
    1100.0
    [m]
    DC
    BIOSTR
    1120.0
    [m]
    DC
    BIOSTR
    1140.0
    [m]
    DC
    BIOSTR
    1160.0
    [m]
    DC
    BIOSTR
    1180.0
    [m]
    DC
    BIOSTR
    1200.0
    [m]
    DC
    BIOSTR
    1220.0
    [m]
    DC
    BIOSTR
    1240.0
    [m]
    DC
    BIOSTR
    1253.0
    [m]
    DC
    BIOSTR
    1259.0
    [m]
    DC
    BIOSTR
    1262.0
    [m]
    DC
    BIOSTR
    1268.0
    [m]
    DC
    BIOSTR
    1280.0
    [m]
    DC
    BIOSTR
    1292.0
    [m]
    DC
    BIOSTR
    1298.0
    [m]
    DC
    BIOSTR
    1304.0
    [m]
    DC
    BIOSTR
    1310.0
    [m]
    DC
    BIOSTR
    1322.0
    [m]
    DC
    BIOSTR
    1331.0
    [m]
    DC
    BIOSTR
    1337.0
    [m]
    DC
    BIOSTR
    1343.0
    [m]
    DC
    BIOSTR
    1355.0
    [m]
    DC
    BIOSTR
    1361.0
    [m]
    DC
    BIOSTR
    1370.0
    [m]
    DC
    BIOSTR
    1382.0
    [m]
    DC
    BIOSTR
    1394.0
    [m]
    DC
    BIOSTR
    1400.0
    [m]
    DC
    BIOSTR
    1406.0
    [m]
    DC
    BIOSTR
    1418.0
    [m]
    DC
    BIOSTR
    1430.0
    [m]
    DC
    BIOSTR
    1433.0
    [m]
    DC
    BIOSTR
    1439.0
    [m]
    DC
    BIOSTR
    1445.0
    [m]
    DC
    BIOSTR
    1451.0
    [m]
    DC
    BIOSTR
    1457.0
    [m]
    DC
    BIOSTR
    1472.0
    [m]
    DC
    BIOSTR
    1481.0
    [m]
    DC
    BIOSTR
    1490.0
    [m]
    DC
    BIOSTR
    1499.0
    [m]
    DC
    BIOSTR
    1508.0
    [m]
    DC
    BIOSTR
    1520.0
    [m]
    DC
    BIOSTR
    1535.0
    [m]
    DC
    BIOSTR
    1550.0
    [m]
    DC
    BIOSTR
    1565.0
    [m]
    DC
    BIOSTR
    1574.0
    [m]
    DC
    BIOSTR
    1583.0
    [m]
    DC
    BIOSTR
    1592.0
    [m]
    DC
    BIOSTR
    1601.0
    [m]
    DC
    BIOSTR
    1610.0
    [m]
    DC
    BIOSTR
    1619.0
    [m]
    DC
    BIOSTR
    1628.0
    [m]
    DC
    BIOSTR
    1637.0
    [m]
    DC
    BIOSTR
    1646.0
    [m]
    DC
    BIOSTR
    1655.0
    [m]
    DC
    BIOSTR
    1664.0
    [m]
    DC
    BIOSTR
    1673.0
    [m]
    DC
    BIOSTR
    1682.0
    [m]
    DC
    BIOSTR
    1691.0
    [m]
    DC
    BIOSTR
    1700.0
    [m]
    DC
    BIOSTR
    1709.0
    [m]
    DC
    BIOSTR
    1718.0
    [m]
    DC
    BIOSTR
    1727.0
    [m]
    DC
    BIOSTR
    1736.0
    [m]
    DC
    BIOSTR
    1745.0
    [m]
    DC
    BIOSTR
    1754.0
    [m]
    DC
    BIOSTR
    1763.0
    [m]
    DC
    BIOSTR
    1772.0
    [m]
    DC
    BIOSTR
    1781.0
    [m]
    DC
    BIOSTR
    1790.0
    [m]
    DC
    BIOSTR
    1799.0
    [m]
    DC
    BIOSTR
    1808.0
    [m]
    DC
    BIOSTR
    1817.0
    [m]
    DC
    BIOSTR
    1826.0
    [m]
    DC
    BIOSTR
    1835.0
    [m]
    DC
    BIOSTR
    1844.0
    [m]
    DC
    BIOSTR
    1850.0
    [m]
    DC
    BIOSTR

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.29

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    MDT GR
    1294
    1776
    MWD - ARC9 VD FRES GR
    474
    1844
    VSP
    454
    1830
    ZAIT MSIP
    996
    1835
    ZAIT MSIP PEX
    996
    1837

  • 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
    474.0
    36
    479.0
    0.00
    LOT
    SURF.COND.
    13 3/8
    996.0
    17 1/2
    1000.0
    1.59
    LOT
    OPEN HOLE
    1857.0
    12 1/4
    1857.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    440
    1.30
    21.0
    Glydril
    1430
    1.27
    17.0
    Glydril
    1690
    1.27
    16.0
    Glydril
    1850
    1.28
    16.0
    Glydril
    1850
    1.27
    18.0
    Glydril