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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6506/11-8

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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.
    6506/11-8
    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).
    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
    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.
    6506/11-8
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    3d survey ST02M04-inline 2660 & crossline 2648
    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 ASA (old)
    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.
    1110-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.
    115
    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,
    24.03.2006
    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.
    16.07.2006
    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.
    16.07.2008
    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.
    15.08.2008
    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.
    OIL
    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
    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.
    TOFTE 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.
    380.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4990.0
    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).
    4988.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    6.2
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    178
    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° 7' 13.6'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    6° 26' 49.3'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7224481.28
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    380172.20
    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.
    5295

  • Wellbore history
    Block 6506/11 is situated on the north-western part of the Halten Terrace offshore Mid-Norway. The well 6506/11-8 was drilled to appraise the 6506/11-7 Morvin Discovery, approximately 10 km north of the Kristin field. The primary objective of the well was to prove extra recoverable oil in structure, explore potential better reservoir properties and reduce depth uncertainties. The primary target was Bathonian age sandstones in the Garn and Ile Formations. Potential targets in the Tofte and Tilje Formations were also investigated by this drilling.
    Operations and results
    Appraisal well 6506/11-8 was spudded with the semi-submersible installation West Alpha on 24 March 2006 and drilled to TD at 4990 m in the early Jurassic Tilje Formation (extended from 4893 m, which was the planned TD of the well). No significant technical problems were encountered in the operations. The well was drilled with seawater and bentonite down to 2150 m, with Glydril water based mud (with glycols) from 2150 m to 4500 m, and with Paratherm oil based mud from 4500 m to TD. No shallow gas was observed by the ROV at the wellhead or by the MWD while drilling the 26" hole.
    The well penetrated rocks of Quaternary, Tertiary, Cretaceous, and Jurassic age. Small gas peaks of up to 3.67% were observed in the lower Lange Sandstone Unit, similar to those observed in the 6506/11-7 well, indicating slight hydrocarbon charging. In the lower Lange Sandstones from 4449 m to 4479 m, very weak shows where observed. The well penetrated the Garn reservoir section at 4622.9 m and the Ile reservoir section at 4734.8 m, both formations shallower than prognosed. A HC discovery was proven both in the Garn and Ile Formations, but the MDT results suggested the formations to be tight. A MDT mini-DST was run in Tofte Formation and confirmed that it contained HC, but was very tight. The MDT data had insufficient resolution to assess gradients and fluid contacts. However, sufficient good pressure points were achieved to conclude that the pressure regime was the same as in the 6506/11-7 well for both the Garn and Ile Formation.
    Eight cores with a total recovered length of 278 m were cut in the well; one was cut in the Spekk/Melke Formation and seven were cut in the Bathonian sandstones. Oil sampling was performed in the Garn (4679 and 4680.7 m), Ile (4773 m) and Tofte (4845.2 m) Formations. Water sampling was performed at 4692.5 m in the Garn Formation. A disappointing high level of contamination in the oil sampling was registered with 10 - 23 % contamination.
    The well was permanently abandoned on 1 July 206 as an oil appraisal.
    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]
    1350.00
    4989.00

  • 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
    2
    4624.0
    4658.4
    [m ]
    3
    4658.4
    4671.4
    [m ]
    4
    4671.4
    4674.2
    [m ]
    5
    4674.4
    4699.8
    [m ]
    6
    4743.0
    4753.0
    [m ]
    7
    4753.0
    4769.4
    [m ]
    8
    4769.4
    4775.4
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    108.1
    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
    2C
    4773.00
    0.00
    CONDENSATE
    YES
    DST
    2B
    0.00
    4578.00
    CONDENSATE
    YES

  • Lithostratigraphy

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    AIT IPLT DSI GR ECRD
    4758
    4989
    CMR APLT ECS ACTS ECRD
    4504
    4897
    DSI AIT APLT ACTS ECRD
    1413
    4505
    MDT MINI DST SAMPLE
    4692
    4782
    MDT MINI DST SAMPLE
    4845
    4845
    MDT PQ SAMPLE
    4500
    4830
    MDT PRESS
    4623
    4870
    MDT SAMPLE MINI DST
    4679
    4679
    MSCT GR
    4599
    4981
    MSCT GR
    4623
    4877
    MWD - ON TRACK
    440
    4990
    PPC MSIP PPC IS AIT ACTS ECRD
    4504
    4897
    VSI GR
    2859
    4985
    VSP GR
    1322
    3554

  • 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
    446.0
    36
    448.0
    0.00
    LOT
    SURF.COND.
    20
    1341.0
    26
    1350.0
    1.72
    LOT
    INTERM.
    14
    2139.0
    17 1/2
    2150.0
    1.86
    LOT
    INTERM.
    9 7/8
    4500.0
    12 1/4
    4500.0
    2.06
    LOT
    OPEN HOLE
    4980.0
    8 1/2
    4980.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    446
    1.06
    SW / BENTONITE 1
    1350
    1.30
    SW / BENTONITE 1
    1823
    1.53
    23.0
    GLYDRIL 18
    2150
    1.62
    25.0
    GLYDRIL 18
    2320
    1.70
    38.0
    PARATHERM
    4500
    1.78
    29.0
    PARATHERM
    4606
    1.86
    34.0
    PARATHERM
    4620
    1.86
    42.0
    PARATHERM
    4624
    1.86
    34.0
    PARATHERM
    4679
    1.86
    43.0
    PARATHERM
    4775
    1.86
    39.0
    PARATHERM

  • 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
    0.28