Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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22.12.2024 - 01:25
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6506/9-2 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.
    6506/9-2 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).
    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
    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
    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.
    6506/9-2
    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.
    Centrica Resources (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.
    1298-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.
    77
    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,
    11.02.2010
    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.
    28.04.2010
    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.
    28.04.2012
    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.
    28.04.2012
    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
    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/CONDENSATE
    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.
    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.
    MIDDLE 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.
    18.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    281.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4805.0
    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).
    4736.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    14.3
    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° 15' 51.04'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    6° 44' 4.36'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7239978.20
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    394237.40
    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.
    6332

  • Wellbore history
    General
    The well 6506/9-2 S was drilled on the Fogelberg prospect in a rotated fault block located on the Halten terrace north-northwest of the Smørbukk and Åsgard fields. The overall objective for the well was to test the hydrocarbon potential in the Middle/Lower Jurassic sandstones of the Fangst and Båt Groups. The expected hydrocarbon phase was light oil with associated gas similar to the nearby 6506/11-7 Morvin light oil discovery. The planned total depth for the well was 4783 m TVD RKB, fulfilling the license obligation of drilling 50 m into the Åre Formation (Båt Group). The well was defined as a HPHT well.
    Operations and results
    Wildcat well 6506/9-2 S was spudded with the semi-submersible installation West Alpha on 11 February 2010 and drilled to TD at 4805 m (4736 m TVD) in the Early Jurassic Åre Formation. The well started with a 9 7/8" pilot hole down to 1227 m to check for shallow gas. No shallow gas was encountered. The well was drilled vertical down to 1213 m. From there angle was built up to 13 deg at ca 1600 m and kept at approximately this angle down to ca 3900 m, and then falling off to vertical again from ca 4000 m to TD. The well was drilled without significant operational problems. It was drilled with seawater and sweeps down to 1219 m, with Glydril water based mud from 1219 m to 2126 m, and with Versatherm oil based mud from 2126 m to TD.
    No hydrocarbons were encountered in the Lysing or Lange formations. High gas readings were encountered in the Lange Formation at 4022 m (3954 m TVD). This coincided with maximum recorded pore pressure in the well and low mud weight. With the correct mud weight circulated in place, the background gas returned to normal level and the drilling operation resumed. Base Cretaceous Unconformity was encountered at 4138 m (4069 m TVD) with 20 m MD Spekk Formation overlying 174 m MD Melke Formation. The target reservoir was penetrated at 4332 m (4263.5 m TVD) with 107.5 m TVD gross gas/condensate in Garn and Ile collectively and a possible GWC at 4440 m (4372 m TVD). Garn and Ile consisted of slightly tighter reservoir sands than initially anticipated. The results of the MDT pressure measurements showed a gas/condensate gradient, equal to 0.029 bar/m, in the Garn and Ile formations. The Tofte Formation was very tight and no gradient could be established. In the Tilje Formation a water gradient is established at 0.096 bar/m. No clear oil shows above OBM were recorded in the well.
    Two conventional cores were cut at 4342 - 4369 m in the Garn Formation and 4416 - 4471 m in the Ile Formation, both with approximately 100% recovery. MDT fluid samples were taken at 4357.98 m in upper Garn Formation (gas/condensate), 4377 m in lower Garn Formation (gas/condensate), 4411.1 m in upper Ile Formation (gas/condensate), 4428 m in lower Ile Formation (gas/condensate), and 4676 m in the Tilje Formation (water).
    The well was permanently abandoned on 28 April 2010 as a gas/condensate 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]
    1225.00
    4805.50

  • 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
    4342.0
    4368.7
    [m ]
    2
    4416.0
    4471.0
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    81.7
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    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
    390.0
    36
    396.0
    0.00
    LOT
    SURF.COND.
    20
    1213.0
    26
    1219.0
    1.71
    LOT
    INTERM.
    13 3/8
    2111.0
    17 1/2
    2126.0
    1.90
    LOT
    INTERM.
    9 5/8
    4197.0
    12 1/4
    4202.0
    2.10
    LOT
    OPEN HOLE
    4806.0
    8 1/2
    4805.0
    0.00
    LOT

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    AIT GPI PPC DSI GR
    4196
    4997
    LDS APS HNGS
    4196
    4799
    LWD - DJ
    299
    1219
    LWD - GEOVIS ECOS SONVIS
    4369
    4805
    LWD - GR RES PWD DJ SON DENS NEU
    2126
    4202
    LWD - GR RES PWD DJ SONIC
    299
    1227
    LWD - GR RES PWD DJ SONIC
    1227
    2126
    LWD - GV STETH ECHO SONVIS
    4202
    4342
    MDT
    4333
    4594
    MDT
    4334
    4463
    MDT
    4375
    4377
    MDT
    4676
    4358
    MSCT
    4345
    4386
    VSI
    1345
    2445
    VSI
    2196
    4795
    XPT
    4333
    4338

  • Lithostratigraphy

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    txt
    0.00
    txt
    0.06

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    1033
    1.02
    Seawater
    1210
    1.31
    16.0
    Glydril WBM
    1795
    1.40
    22.0
    Glydril WBM
    1955
    1.39
    20.0
    Glydril WBM
    2125
    1.54
    25.0
    Glydril
    2680
    1.72
    69.0
    Versatec
    4156
    1.77
    66.0
    Versatherm
    4202
    1.80
    79.0
    Versatherm
    4213
    1.89
    38.0
    Versatherm
    4470
    1.89
    46.0
    Versatherm
    4805
    1.89
    62.0
    Versatherm
    4805
    1.89
    61.0
    Versatherm

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    4212.0
    [m]
    DC
    APT
    4221.0
    [m]
    DC
    APT
    4230.0
    [m]
    DC
    APT
    4239.0
    [m]
    DC
    APT
    4248.0
    [m]
    DC
    APT
    4266.0
    [m]
    DC
    APT
    4275.0
    [m]
    DC
    APT
    4284.0
    [m]
    DC
    APT
    4293.0
    [m]
    DC
    APT
    4302.0
    [m]
    DC
    APT
    4311.0
    [m]
    DC
    APT
    4320.0
    [m]
    DC
    APT
    4329.0
    [m]
    DC
    APT
    4338.0
    [m]
    DC
    APT
    4371.0
    [m]
    DC
    APT
    4380.0
    [m]
    DC
    APT
    4389.0
    [m]
    DC
    APT
    4398.0
    [m]
    DC
    APT
    4407.0
    [m]
    DC
    APT
    4416.0
    [m]
    DC
    APT
    4473.0
    [m]
    DC
    APT
    4482.0
    [m]
    DC
    APT
    4491.0
    [m]
    DC
    APT
    4500.0
    [m]
    DC
    APT
    4509.0
    [m]
    DC
    APT
    4518.0
    [m]
    DC
    APT
    4527.0
    [m]
    DC
    APT
    4536.0
    [m]
    DC
    APT
    4545.0
    [m]
    DC
    APT
    4554.0
    [m]
    DC
    APT
    4563.0
    [m]
    DC
    APT
    4581.0
    [m]
    DC
    APT
    4590.0
    [m]
    DC
    APT
    4599.0
    [m]
    DC
    APT
    4608.0
    [m]
    DC
    APT
    4617.0
    [m]
    DC
    APT
    4626.0
    [m]
    DC
    APT
    4635.0
    [m]
    DC
    APT
    4644.0
    [m]
    DC
    APT
    4653.0
    [m]
    DC
    APT
    4662.0
    [m]
    DC
    APT
    4671.0
    [m]
    DC
    APT
    4680.0
    [m]
    DC
    APT
    4689.0
    [m]
    DC
    APT
    4698.0
    [m]
    DC
    APT
    4707.0
    [m]
    DC
    APT
    4716.0
    [m]
    DC
    APT
    4725.0
    [m]
    DC
    APT
    4734.0
    [m]
    DC
    APT
    4743.0
    [m]
    DC
    APT
    4752.0
    [m]
    DC
    APT
    4761.0
    [m]
    DC
    APT
    4770.0
    [m]
    DC
    APT
    4779.0
    [m]
    DC
    APT
    4788.0
    [m]
    DC
    APT
    4797.0
    [m]
    DC
    APT
    4805.0
    [m]
    DC
    APT