Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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23.11.2024 - 01:30
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6507/3-8

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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.
    6507/3-8
    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
    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.
    6507/3-8
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    3D survey :ST03M03-inline 5177 & xline 2967
    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.
    Statoil Petroleum 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.
    1286-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.
    37
    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,
    09.11.2009
    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.
    15.12.2009
    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.
    15.12.2011
    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.
    10.01.2012
    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/GAS
    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.
    MIDDLE 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.
    FANGST GP
    2nd level with HC, age
    Age of lithostratigraphic unit, 2nd level, where hydrocarbons were encountered. Examples of legal values: CRETACEOUS, EARLY CRETACEOUS, LATE JURASSIC, EOCENE.
    EARLY JURASSIC
    2nd level with HC, formation
    Name of lithostartigraphic unit, 2nd 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.
    BÅT GP
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    22.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    379.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2990.0
    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).
    2990.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    2.9
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    113
    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.
    TILJE FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    65° 59' 28.3'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    7° 59' 27.6'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7319482.41
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    454188.40
    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.
    6258

  • Wellbore history
    General
    Well 6507/3-8 was drilled on the Gjøk prospect between the Alve and Norne Fields on the western flank of the Nordland Ridge in the Norwegian Sea. The well objective was to prove economical HC volumes in the Fangst and Båt groups and to secure the necessary data for a future development and tie-back to the Norne field
    Operations and results
    Wildcat well 6507/3-8 was spudded with the semi-submersible installation Ocean Vanguard on 9 November 2009 and drilled to TD at 2990 in the Early Jurassic Tilje Formation. No significant technical problem was encountered in the operations. The well was drilled with seawater and sweeps down to 1303 m and with Performadril WBM from 1303 m to TD. No shallow gas was observed.
    The well penetrated Tertiary, Cretaceous, and Jurassic formations. Top Jurassic, Spekk Formation was encountered at 2534 m. A 142 m thick gas column was proven in Not, Ile and Tofte Formations and a 9.5 m thick oil column in Tofte Formation. The Not Formation was penetrated at 2693 m which was 6 meters deeper than prognosed, but the three main reservoir levels were 32 m thicker than prognosed. The gas-oil contact was proven at 2835 m and the oil-water contact at 2844 m. No oil shows were recorded outside of the hydrocarbon bearing reservoir in the well.
    Five cores were cut, one in the Not Formation, one in the Ile Formation, one across the Ile/Tofte formation boundary and two in the Tofte Formation. MDT pressure measurements were collected in Not, Ile, Tofte and Tilje formations. The sandstones had good reservoir properties, and pressure measurements of good quality were achieved. The reservoir fluids were gas, oil and water. The gas zone was divided into two different pressure regimes with a pressure difference of approximately 0.5 Bar between the Not and the Ile/Tilje formations. Gas samples were collected at 2694.5 m and 2796 m in the Not and Tofte formations. Oil samples were collected at 2842.5 m in the Tofte oil zone. A water sample was collected at 2872 m in the Tilje formation. The water sample was collected in the same pressure regime as the hydrocarbons above. All hydrocarbon samples were collected with low drawdown and had good quality. The water sample contained approximately 10% mud filtrate, but is regarded to have reasonable quality.
    The well was permanently abandoned on 15 December 2009 as an oil and gas discovery
    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]
    1310.00
    2991.00

  • 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
    2695.0
    2715.1
    [m ]
    2
    2743.0
    2783.2
    [m ]
    3
    2784.0
    2794.6
    [m ]
    4
    2795.0
    2822.2
    [m ]
    5
    2822.0
    2844.3
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    120.4
    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
    1310.0
    [m]
    DC
    BIOSTRAT
    1330.0
    [m]
    DC
    BIOSTR
    1350.0
    [m]
    DC
    BIOSTR
    1370.0
    [m]
    DC
    BIOSTR
    1390.0
    [m]
    DC
    BIOSTR
    1410.0
    [m]
    DC
    BIOSTR
    1430.0
    [m]
    DC
    BIOSTR
    1450.0
    [m]
    DC
    BIOSTR
    1470.0
    [m]
    DC
    BIOSTR
    1490.0
    [m]
    DC
    BIOSTR
    1510.0
    [m]
    DC
    BIOSTR
    1530.0
    [m]
    DC
    BIOSTR
    1550.0
    [m]
    DC
    BIOSTR
    1570.0
    [m]
    DC
    BIOSTR
    1590.0
    [m]
    DC
    BIOSTR
    1610.0
    [m]
    DC
    BIOSTR
    1630.0
    [m]
    DC
    BIOSTR
    1650.0
    [m]
    DC
    BIOSTR
    1670.0
    [m]
    DC
    BIOSTR
    1690.0
    [m]
    DC
    BIOSTR
    1710.0
    [m]
    DC
    BIOSTR
    1730.0
    [m]
    DC
    BIOSTR
    1750.0
    [m]
    DC
    BIOSTR
    1770.0
    [m]
    DC
    BIOSTR
    1790.0
    [m]
    DC
    BIOSTR
    1810.0
    [m]
    DC
    BIOSTR
    1830.0
    [m]
    DC
    BIOSTR
    1850.0
    [m]
    DC
    BIOSTR
    1870.0
    [m]
    DC
    BIOSTR
    1890.0
    [m]
    DC
    BIOSTR
    1910.0
    [m]
    DC
    BIOSTR
    1930.0
    [m]
    DC
    BIOSTR
    1950.0
    [m]
    DC
    BIOSTR
    1970.0
    [m]
    DC
    BIOSTR
    1980.0
    [m]
    DC
    BIOSTR
    1990.0
    [m]
    DC
    BIOSTR
    2000.0
    [m]
    DC
    BIOSTR
    2010.0
    [m]
    DC
    BIOSTR
    2020.0
    [m]
    DC
    BIOSTR
    2030.0
    [m]
    DC
    BIOSTR
    2040.0
    [m]
    DC
    BIOSTR
    2050.0
    [m]
    DC
    BIOSTR
    2060.0
    [m]
    DC
    BIOSTR
    2070.0
    [m]
    DC
    BIOSTR
    2080.0
    [m]
    DC
    BIOSTR
    2090.0
    [m]
    DC
    BIOSTR
    2100.0
    [m]
    DC
    BIOSTR
    2110.0
    [m]
    DC
    BIOSTR
    2120.0
    [m]
    DC
    BIOSTR
    2130.0
    [m]
    DC
    BIOSTR
    2140.0
    [m]
    DC
    BIOSTR
    2150.0
    [m]
    DC
    BIOSTR
    2160.0
    [m]
    DC
    BIOSTR
    2170.0
    [m]
    DC
    BIOSTR
    2180.0
    [m]
    DC
    BIOSTR
    2190.0
    [m]
    DC
    BIOSTR
    2200.0
    [m]
    DC
    BIOSTR
    2210.0
    [m]
    DC
    BIOSTR
    2220.0
    [m]
    DC
    BIOSTR
    2230.0
    [m]
    DC
    BIOSTR
    2240.0
    [m]
    DC
    BIOSTR
    2250.0
    [m]
    DC
    BIOSTR
    2260.0
    [m]
    DC
    BIOSTR
    2270.0
    [m]
    DC
    BIOSTR
    2280.0
    [m]
    DC
    BIOSTR
    2290.0
    [m]
    DC
    BIOSTR
    2300.0
    [m]
    DC
    BIOSTR
    2310.0
    [m]
    DC
    BIOSTR
    2320.0
    [m]
    DC
    BIOSTR
    2330.0
    [m]
    DC
    BIOSTR
    2340.0
    [m]
    DC
    BIOSTR
    2350.0
    [m]
    DC
    BIOSTR
    2360.0
    [m]
    DC
    BIOSTR
    2370.0
    [m]
    DC
    BIOSTR
    2380.0
    [m]
    DC
    BIOSTR
    2390.0
    [m]
    DC
    BIOSTR
    2400.0
    [m]
    DC
    BIOSTR
    2410.0
    [m]
    DC
    BIOSTR
    2420.0
    [m]
    DC
    BIOSTR
    2430.0
    [m]
    DC
    BIOSTR
    2439.0
    [m]
    DC
    BIOSTR
    2448.0
    [m]
    DC
    BIOSTR
    2457.0
    [m]
    DC
    BIOSTR
    2466.0
    [m]
    DC
    BIOSTR
    2475.0
    [m]
    DC
    BIOSTR
    2484.0
    [m]
    DC
    BIOSTR
    2493.0
    [m]
    DC
    BIOSTR
    2502.0
    [m]
    DC
    BIOSTR
    2511.0
    [m]
    DC
    BIOSTR
    2520.0
    [m]
    DC
    BIOSTR
    2529.0
    [m]
    DC
    BIOSTR
    2538.0
    [m]
    DC
    BIOSTR
    2547.0
    [m]
    DC
    BIOSTR
    2556.0
    [m]
    DC
    BIOSTR
    2562.0
    [m]
    DC
    BIOSTR
    2568.0
    [m]
    DC
    BIOSTR
    2784.0
    [m]
    C
    BIOSTR
    2785.0
    [m]
    C
    BIOSTR
    2786.0
    [m]
    C
    BIOSTR
    2787.0
    [m]
    C
    BIOSTR
    2788.0
    [m]
    C
    BIOSTR
    2789.0
    [m]
    C
    BIOSTR
    2790.0
    [m]
    C
    BIOSTR
    2791.0
    [m]
    C
    BIOSTR
    2792.0
    [m]
    C
    BIOSTR
    2793.0
    [m]
    C
    BIOSTR
    2794.0
    [m]
    C
    BIOSTR
    2795.0
    [m]
    C
    BIOSTR
    2796.0
    [m]
    C
    BIOSTR
    2797.0
    [m]
    C
    BIOSTR
    2798.0
    [m]
    C
    BIOSTR
    2799.0
    [m]
    C
    BIOSTR
    2800.0
    [m]
    C
    BIOSTR
    2801.0
    [m]
    C
    BIOSTR
    2802.0
    [m]
    C
    BIOSTR
    2803.0
    [m]
    C
    BIOSTR
    2804.0
    [m]
    C
    BIOSTR
    2805.0
    [m]
    C
    BIOSTR
    2806.0
    [m]
    C
    BIOSTR
    2807.0
    [m]
    C
    BIOSTR
    2808.0
    [m]
    C
    BIOSTR
    2809.0
    [m]
    C
    BIOSTR
    2810.0
    [m]
    C
    BIOSTR
    2811.0
    [m]
    C
    BIOSTR
    2812.0
    [m]
    C
    BIOSTR
    2813.0
    [m]
    C
    BIOSTR
    2814.0
    [m]
    C
    BIOSTR
    2815.0
    [m]
    C
    BIOSTR
    2816.0
    [m]
    C
    BIOSTR
    2817.0
    [m]
    C
    BIOSTR
    2818.0
    [m]
    C
    BIOSTR
    2819.0
    [m]
    C
    BIOSTR
    2820.0
    [m]
    C
    BIOSTR
    2821.0
    [m]
    C
    BIOSTR
    2822.0
    [m]
    C
    BIOSTR
    2823.0
    [m]
    C
    BIOSTR
    2824.0
    [m]
    C
    BIOSTR
    2825.0
    [m]
    C
    BIOSTR
    2826.0
    [m]
    C
    BIOSTR
    2827.0
    [m]
    C
    BIOSTR
    2828.0
    [m]
    C
    BIOSTR
    2829.0
    [m]
    C
    BIOSTR
    2830.0
    [m]
    C
    BIOSTR
    2831.0
    [m]
    C
    BIOSTR
    2832.0
    [m]
    C
    BIOSTR
    2833.0
    [m]
    C
    BIOSTR
    2834.0
    [m]
    C
    BIOSTR
    2835.0
    [m]
    C
    BIOSTR
    2836.0
    [m]
    C
    BIOSTR
    2837.0
    [m]
    C
    BIOSTR
    2838.0
    [m]
    C
    BIOSTR
    2839.0
    [m]
    C
    BIOSTR
    2840.0
    [m]
    C
    BIOSTR
    2841.0
    [m]
    C
    BIOSTR
    2842.0
    [m]
    C
    BIOSTR
    2843.0
    [m]
    C
    BIOSTR
    2843.5
    [m]
    C
    BIOSTR
    2844.3
    [m]
    C
    BIOSTR

  • Lithostratigraphy

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CMR ECS
    2662
    2990
    HRLA PEX
    2662
    2990
    MDT
    2694
    2967
    MDT
    2796
    2796
    MSIP
    1800
    2990
    MWD LWD - ARCVRES8 TELE
    1300
    2663
    MWD LWD - ARCVRES9 PP
    465
    1300
    MWD LWD - DIR
    400
    462
    MWD LWD - GVR6 ARCVRES6 TELE
    2663
    2990
    VSP
    480
    2975

  • 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
    462.0
    36
    465.0
    0.00
    LOT
    SURF.COND.
    13 3/8
    1295.0
    17 1/2
    1300.0
    0.00
    LOT
    INTERM.
    9 5/8
    2662.0
    12 1/2
    2663.0
    0.00
    LOT
    OPEN HOLE
    2990.0
    8 1/2
    2990.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    1300
    1.50
    22.0
    Performadril
    1390
    1.50
    20.0
    Performadril
    1793
    1.50
    28.0
    Performadril
    2021
    1.50
    26.0
    Performadril
    2205
    1.50
    37.0
    Performadril
    2311
    1.50
    32.0
    Performadril
    2480
    1.51
    37.0
    Performadril
    2662
    1.52
    23.0
    Performadril
    2663
    1.51
    21.0
    Performadril
    2695
    1.25
    16.0
    Performadril
    2716
    1.25
    16.0
    Performadril
    2822
    1.25
    15.0
    Performadril
    2990
    1.25
    15.0
    Performadril

  • 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
    0.27