Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
22.12.2024 - 01:25
Time of last synchronization with Norwegian Offshore Directorate's internal systems

6506/9-4 S

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.
    6506/9-4 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
    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
    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.
    1686-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.
    84
    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,
    03.02.2018
    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.
    27.04.2018
    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.
    27.04.2020
    Plugged date
    Date when plugging operations was finished, as reported by the operator to the Norwegian Offshore Directorate through DDRS (Daily Drilling Reporting System).
    27.04.2018
    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.
    27.04.2020
    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
    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).
    4738.0
    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).
    4611.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    20.7
    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.
    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.
    8355

  • Wellbore history
    General
    Well 6506/9-4 S was drilled appraise the 6506/9-2 S Fogelberg discovery. The Fogelberg discovery is located on a small fault block on the Halten Terrace, north-northwest of the Smørbukk Field and northeast of the Morvin Field. The primary objective was to reduce the volume uncertainties of the discovery by establishing the hydrocarbon contacts within the Garn and Ile Formations, verifying reservoir quality, and collecting representative fluid samples.
    Operations and results
    A 9 7/8" pilot hole was drilled to 1381 m in order to check for shallow gas. No shallow gas was encountered.
    Appraisal well 6506/9-4 S was spudded with the semi-submersible installation Island Innovator on 3 February 2018 and drilled to TD at 4738 m in the Early Jurassic Tofte Formation. Low penetration rate was experienced in the Lange Formation shales in the 12 ¼” section. After logging at final TD liner was run to perform a DST. The liner hanger running tool stuck in cement, leading to a significant period of NPT. The well was drilled with seawater and hi-vis pills down to 1381 m and with RheGuard Prime oil-based mud from 1381 m to TD.
    The Garn formation was encountered at 4520 m (4405 m TVD), 14 m shallower than prognosis and the top Ile Formation was picked at 4591.5 m (4475.0 m TVD), 13 m shallower than the prognosis. Approximately 67 m gross of gas bearing sandstone was proven in the Garn Formation whilst 70 m gross of sandstone with high water saturation was encountered in the Ile Formation. The gas-water contact(s) was not observed in the well. The reservoir quality of the Garn formation is variable, ranging from moderate to high, in line with the previous understanding of the reservoir. The reservoir quality of the Ile Formation is poor in the well.
    There were no reliable oil shows above the OBM in the well. Elevated resistivity and gas readings in the Cretaceous Intra-Lange and Lysing formation sandstones indicate some HC saturation, possibly with a small pocket of live hydrocarbons in Lysing. The intra-Lange sandstones were seen in the intervals 4031 to 4110 m and 4174 to 4244 m. All three Cretaceous intervals were however considered tight without flow potential.
    Four successive cores were cut from 4520 to 4618.8 m in the Garn, Not and Ile formations. Core recoveries varied from 96 to 104%. MDT fluid samples were taken at 4532.8 m (condensate and gas), 4553 m (condensate and gas) and 4568.7 m (hydrocarbons).
    The well was permanently abandoned on 27 April as a gas appraisal 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]
    1390.00
    4738.00

  • 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
    4520.0
    4546.0
    [m ]
    2
    4546.1
    4584.7
    [m ]
    3
    4584.9
    4590.5
    [m ]
    4
    4590.7
    4618.9
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    98.4
    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
    MDT
    0.00
    0.00
    YES
    MDT
    4325.00
    4290.00
    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
    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
    INTERM.
    14
    2284.0
    17 1/2
    2290.0
    0.00
    2293.0
    0.0
    1.96
    LOT
    LINER
    9 7/8
    4463.0
    12 1/4
    4465.0
    2.18
    LOT
    OPEN HOLE
    4738.0
    8 1/2
    4738.0
    0.00

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    DEN NEU SPGR MAGRES
    4450
    4740
    FTNG SAMP
    4450
    4550
    HXPT PP
    4450
    4740
    LWD - DI
    331
    397
    LWD - GR RES PWD DI NEU DEN CAL
    4500
    4738
    LWD - GR RES PWD DI SON
    331
    2290
    LWD - GR RES PWD DI SON NEU DEN
    2290
    4519
    MDT SAT SAMP
    4450
    4600
    MDT SAT SAMP
    4568
    4569
    RES IMG SON GR
    4450
    4740
    SEIS VSI4
    473
    4482

  • Lithostratigraphy

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    351
    1.03
    10.0
    Hivis Bentonite Sweeps
    397
    1.03
    10.0
    Hivis Bentonite Mud
    397
    1.34
    32.0
    Glydril
    817
    1.03
    10.0
    Hivis Bentonite Sweeps
    1198
    1.03
    10.0
    Hivis Bentonite Mud
    1361
    1.34
    19.0
    Glydril
    1381
    1.02
    1.0
    Glydril
    1381
    1.03
    10.0
    Bentonite
    1385
    1.39
    32.0
    OBM
    1710
    1.59
    42.0
    Rheguard Prime
    2119
    1.59
    46.0
    OBM
    2360
    1.69
    49.0
    OBM
    3139
    1.69
    47.0
    OBM
    3621
    1.80
    64.0
    OBM
    4419
    1.77
    53.0
    OBM
    4465
    1.80
    55.0
    OBM
    4547
    1.77
    52.0
    OBM
    4738
    1.64
    41.0
    OBM
    4738
    1.80
    60.0
    OBM