Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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26.11.2024 - 01:27
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6506/11-11 S

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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.
    6506/11-11 S
    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
    Press release
    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
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    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.
    6506/11-11
    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.
    OMV (Norge) 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.
    1767-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.
    151
    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,
    31.05.2019
    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.
    28.10.2019
    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.
    28.10.2021
    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.
    28.10.2019
    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.
    10.11.2021
    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.
    APPRAISAL
    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.
    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.
    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.
    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.
    GARN 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.
    382.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4443.0
    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).
    4433.0
    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.
    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.
    ROR FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    65° 12' 10.5'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    6° 22' 46.77'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7233796.58
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    377393.02
    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.
    8759

  • Wellbore history
    Operations and results
    Well 6506/11-11 S was entered with the semi-submersible Deepsea Bergen rig on 31 May 2019 and was drilled to TD at 4443 m (4432.7 m TVD) in the Early Jurassic Ror Formation. The well was drilled down to 469.5 m with seawater and high viscosity pills, from 469.5 to 1426 m with KCl Polymer mud and RMR system in place, from 1426 to 2625 m with KCl Glydril water-based mud, and from 2625 m to TD with RheGuard oil-based mud. The well was initially planned to be vertically drilled, but due to presence of corrals the location was moved approximately 80 m westwards.
    Top of intra-Lange (informally Breiflabb Member) sandstones was penetrated at 3912 m (3879 m TVD MSL) and was water bearing without evidence of a hydrocarbon-water contact. Further Intra-Lange Formation (informally Smørflyndre Member) came in at 3952 m (3919 m TVD MSL) and has indications of hydrocarbon presence based on log interpretation without clear hydrocarbon-water contact. The Garn Formation was penetrated at 4141 (4107 m TVD MSL) m and can be separated into three lithostratigraphic intervals. The uppermost sandstone is a good reservoir. The bioturbated silt rich sandstone sequence below this is cemented and therefore of poor reservoir quality. An older sandstone of good reservoir quality is present at the base. The reservoir is saturated with gas-condensate at initial reservoir conditions with a gas-down-to contact at 4207.6 m (4174.4 m TVD MSL). The Ile Formation was penetrated at 4209 m (4175.9 m TVD MSL) and consists of several water bearing sandstone layers of good porosity and flow capacity. Three cores were cut, all in Garn Formation retrieving 41.53 m of cores. 21 SWC plugs covering Breiflabb and Smørflyndre members and Lyr, Garn and Ile formations were successfully drilled. MDT fluid samples were taken at 4142.3 m (gas condensate), 4166 m (gas condensate), 4186.3 m (gas condensate), and 4274.9 m (water).
    The well was permanently plugged and abandoned on 28 October 2019 as a gas appraisal well.
    Testing
    Two successful DSTs were performed in the Garn Formation.

  • 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]
    474.00
    4443.00

  • 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
    4150.0
    4157.0
    [m ]
    2
    4158.0
    4172.2
    [m ]
    3
    4173.0
    4193.4
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    41.5
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Oil samples at the Norwegian Offshore Directorate
    Oil samples at the Norwegian Offshore Directorate
    Test type
    Bottle number
    Top depth
    MD [m]
    Bottom depth
    MD [m]
    Fluid type
    Test time
    Samples available
    DST
    DST 1A
    4199.70
    4190.00
    WATER
    06.09.2019 - 14:22
    YES
    DST
    DST 1A
    4199.70
    4190.00
    OIL
    06.09.2019 - 14:07
    YES
    DST
    DST 2
    4162.68
    4140.34
    OIL
    28.09.2019 - 04:39
    YES
    DST
    DST 2
    4162.68
    4140.34
    WATER
    29.09.2019 - 18:20
    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
    470.0
    36
    470.0
    0.00
    SURF.COND.
    20
    1420.0
    26
    1420.0
    1.68
    FIT
    INTERM.
    13 3/8
    2618.0
    17 1/2
    2619.0
    1.98
    LOT
    INTERM.
    9 5/8
    3810.0
    12 1/4
    3820.0
    2.15
    FIT
    LINER
    7
    4432.0
    8 1/2
    4433.0
    0.00

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    0
    0
    0.0
    2.0
    0
    0
    0.0
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    2.0
    Drill stem tests (DST)
    Test number
    Oil
    [Sm3/day]
    Gas
    [Sm3/day]
    Oil density
    [g/cm3]
    Gas grav. rel.air
    GOR
    [m3/m3]
    1.0
    2.0

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    HXPT GR
    4212
    4326
    IS CBL VDL GR
    2610
    3410
    IS CBL VDL GR LINER
    2610
    3410
    LWD - ABG EWR4 DGR XBAT
    2625
    3827
    LWD - ALD CTN EWR GM
    3827
    4443
    LWD - EWR4 DGR XBAT
    409
    2625
    MDT
    4142
    4274
    QAIT EMS PPC MSIP QGEO GR
    3819
    4441
    VSI4 ZOVSP
    388
    4423
    XHPT APS LDS ECS HNGS CMR GR
    3819
    4441
    XLR
    3915
    4203
    XLR
    4233
    4273

  • Lithostratigraphy

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    46
    1.49
    25.0
    1.5Sg Spud / Kill Mud
    110
    1.49
    35.0
    1.5Sg Spud Mud
    110
    1.29
    12.0
    KCl Polymer
    509
    1.34
    15.0
    KCl Polymer
    613
    1.30
    13.0
    KCl Polymer
    953
    1.39
    16.0
    KCl Polymer
    1033
    1.29
    12.0
    KCl Polymer
    1314
    1.39
    13.0
    KCl Polymer
    1426
    1.39
    13.0
    KCl Polymer
    1426
    1.44
    39.0
    Glydril WBM
    2040
    1.62
    38.0
    Glydril WBM
    2625
    1.62
    38.0
    Glydril WBM
    2628
    1.66
    23.0
    Rheguard OBM
    2628
    1.64
    45.0
    Rheguard OBM
    3030
    1.66
    50.0
    Rheguard OBM
    3762
    1.76
    72.0
    Rheguard OBM
    3827
    1.76
    55.0
    Rheguard OBM
    3827
    1.84
    24.0
    Rheguard OBM
    3897
    1.85
    27.0
    Rheguard OBM
    4050
    1.85
    32.0
    Rheguard OBM
    4136
    1.96
    42.0
    Rheguard OBM
    4150
    1.96
    43.0
    Rheguard OBM
    4150
    1.90
    35.0
    Rheguard OBM
    4442
    1.68
    CaBr brine
    4442
    1.91
    39.0
    Rheguard OBM
    4442
    1.64
    CaBr2 brine
    4443
    1.91
    46.0
    Rheguard OBM
    4443
    1.14
    NaCl brine
    4443
    1.91
    70.0
    1.92 sg OBM MW 50