Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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05.11.2024 - 01:27
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6506/9-4 A

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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.
    6506/9-4 A
    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
    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
    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.
    6506/9-4
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    CE08M1FB. Inline 2687 Crossline 2602
    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.
    Spirit Energy 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.
    1694-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.
    78
    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,
    28.04.2018
    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.
    13.07.2018
    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.
    14.07.2018
    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.
    13.07.2020
    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.
    14.07.2020
    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.
    APPRAISAL
    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.
    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.
    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
    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.
    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.
    ILE FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    30.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    301.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4497.0
    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).
    4458.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    11.2
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    159
    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.
    TOFTE FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    65° 15' 38.11'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    6° 42' 35.62'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7239619.65
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    393072.48
    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.
    8411

  • Wellbore history
    General
    Well 6506/9-4 A is a geological side-track to well 6506/9-4 S, drilled on The Fogelberg Discovery on a small fault block on the Halten Terrace, north-northwest of the Smørbukk Field and northeast of the Morvin Field. The side-track was drilled up-flank to the crestal part of the structure where future production wells would be located. The primary objective of the side-track was to perform a DST and collect representative fluid samples.
    Operations and results
    Appraisal well 6506/9-4 A was kicked off in 14” casing at 2201 m on 28 April 2018. It was drilled with the semi-submersible installation Island Innovator to TD at 4497 m (4458 m TVD) m in the Early Jurassic Tofte Formation. Low penetration rate was experienced in the Lange Formation shales in the 12 ¼” section . The well was drilled with RheGuard Prime oil-based mud from kick-off to TD.
    The Garn Formation was encountered at 4289.5 m (4254 m TVD), 13.5 m shallower than prognosis and top Ile Formation was picked at 4350.5 m (4313.8 m TVD), 13 m shallower than the prognosis. Approximately 57 m TVD gross sandstone of moderate to high quality was encountered in the Garn Formation and 66 m TVD gross moderate quality sandstone in the Ile Formation. Both formations were gas bearing.
    Shows in the form of cut fluorescence was observed in several Intra-Lange sandstones, but not significantly different from the fluorescence caused by the oil-based mud.
    Two cores were cut in succession from 4288.9 to 4341 m in the Garn Formation. The core recovery was 80.04% and 98.38% fore core 1 and 2, respectively. The core-log depth shifts were +1.8m and +1.1 m for core 1 and 2, respectively. No fluid sample was taken on wire line.
    The well was permanently abandoned on 13 July 2018 as a gas appraisal well.
    Testing
    A drill stem test was conducted from the interval 4290.0 - 4325.0 m (4253.4-4287.4 m TVD) in the Garn Formation. Maximum production rate from the formation was 570 000 Sm3 of gas and 80 Sm3 of condensate per day through a 36/64 inches choke opening. The gas contains 6 ppm H2S and 4-5% CO2. The temperature recorded in the test was 153 °C.

  • 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]
    2220.00
    4497.00

  • 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
    4288.9
    4310.7
    [m ]
    2
    4316.2
    4340.6
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    46.2
    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
    0.00
    0.00
    YES
    DST
    4325.00
    4191.60
    CONDENSATE
    23.06.2018 - 17:53
    YES
    MDT
    4325.00
    4290.00
    CONDENSATE
    23.06.2018 - 17:45
    YES

  • Lithostratigraphy

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    4290
    4325
    14.3
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    153
    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
    80
    570000

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    APS LDS ADT HNGS CMR
    3103
    4499
    IBC CBL PMIT
    335
    2188
    LWD - GR RES PWD DI SON NEU DEN
    2201
    4497
    PS LPD XLDP HY PC GR
    4299
    4399
    PS XLDP HY PC GR
    4292
    4296
    QAIT QGEO PPC MSIP GR
    3103
    4499

  • 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
    397.0
    36
    397.5
    0.00
    SURF.COND.
    20
    1374.5
    26
    1381.0
    1.60
    LOT
    PILOT HOLE
    1381.0
    9 7/8
    1381.0
    0.00
    2201.0
    0.0
    1.93
    FIT
    INTERM.
    14
    2284.0
    17 1/2
    2200.0
    0.00
    INTERM.
    9 7/8
    4249.0
    12 1/4
    4250.0
    2.10
    LOT
    LINER
    7
    4496.0
    8 1/2
    4497.0
    0.00

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    2211
    1.64
    42.0
    Rheguard
    2525
    1.69
    53.0
    Rheguard
    3469
    1.78
    64.0
    Rheguard
    3577
    1.74
    56.0
    Rheguard
    3754
    1.75
    63.0
    Rheguard
    3936
    1.76
    63.0
    Rheguard
    4150
    1.78
    66.0
    Rheguard
    4250
    1.79
    64.0
    Rheguard
    4288
    1.74
    56.0
    Rheguard
    4314
    1.75
    54.0
    Rheguard
    4497
    1.75
    58.0
    Rheguard
    4497
    1.77
    69.0
    Rheguard
    4497
    1.14
    Calcium Chloride Brine
    4497
    1.75
    58.0
    Rheguard
    4497
    1.50
    34.0
    Rheguard OBM
    4497
    1.29
    6.0
    WBM
    4497
    1.02
    WBM