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

6608/10-8

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.
    6608/10-8
    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).
    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
    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.
    6608/10-8
    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.
    1024-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.
    105
    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,
    29.12.2001
    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.
    12.04.2002
    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.
    12.04.2004
    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.
    18.05.2004
    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.
    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.
    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.
    INTRA MELKE FM SS
    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.
    FANGST GP
    3rd level with HC, age
    Age of lithostratigraphic unit, 3rd level, where hydrocarbons were encountered. Examples of legal values: CRETACEOUS, EARLY CRETACEOUS, LATE JURASSIC, EOCENE.
    EARLY JURASSIC
    3rd level with HC, formation
    Name of lithostartigraphic unit, 3rd 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.
    BÅT GP
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    24.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    376.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2652.0
    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).
    2650.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    5.6
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    97
    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.
    66° 3' 34.07'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    8° 10' 42.92'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7326967.49
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    462804.74
    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.
    4439

  • Wellbore history
    General
    Well 6608/10-8 was drilled in the Nordland II area on the Stµr structure, ca 3 km north east of the Norne Field. Geologically the structure is part of the D°nna Terrace. The primary objective of the well was to prove hydrocarbons in sandstones of the Middle to Early Jurassic Garn, Ile, Tofte, and Åre Formations. The hydrocarbon potential of the Melke Formation of Late Jurassic age was considered as secondary objective.
    Operations and results
    Exploration well 6608/10-8 was spudded with the semi-submersible installation Stena Don on 29 December 2001 and drilled to TD at 2652 m (2626 m TVD MSL) in the Early Jurassic Åre Formation. The well was drilled with seawater down to 1315 m, and with Aquadril (KCl / polymer / glycol mud) from 1315 m to TD. No shallow gas was encountered and drilling went without significant technical difficulties.
    Top Melke sandstone came in at 2224 m, top Not sandstone at 2348 m, top Ile Formation at 2389 m, top Tilje Formation at 2391 m, and top Åre Formation at 2402.5 m. Oil was encountered in sandstones of the Melke, Not, Ile, Tilje, and Åre Formations. An OWC was found at 2483.7 m (2458.1 m TVD MSL) in the Åre Formation, based on petrophysical interpretation. Wire line MDT pressure measurements were not useful for establishing the OWC. The oil was verified by shows and laboratory analyses of cores, logs, and fluid samples. Oil samples were taken on wire line in all oil bearing reservoir zones in the well. Good oil shows were reported from 2226 m down to 2486 m. The composition of the oil samples from the Not and Åre Formations was very similar to that of the oil on the Norne Field.
    Seven cores were cut in the Melke, Not, Ile, Tilje, and Åre Formations, recovering a total of 94.1 m. Coring in Åre proved difficult due to a heterogeneous sand/shale lithology. Three MDT runs were performed. Forty-six pressure points were taken in the first. In the second oil samples were taken in the Not Formation at 2407.5 m MSL, in the Tilje Formation at 2439.5 m MSL, and in the Åre Formation at 2351.5 m MSL. The third run was conducted with dual packer in the Melke Formation and a "Mini-DST" was carried out. Oil samples were taken at 2271 m MSL. All samples were of good quality. Results from the testing proved pressure depletion in the Middle and Lower Jurassic section as a result of the production on the Norne Field. The Not Formation showed the largest pressure depletion. The degree of pressure depletion varied between the different sand stone layers in the reservoir, making it difficult to establish fluid gradients. The most reliable gradients are assumed to be those established by PVT analyses. The Melke Formation sandstones did not exhibit pressure depletion.
    The well bore was plugged back to 10 m into the 13 3/8" casing and prepared for side-tracking. Well bore 6608/10-8 was abandoned as an oil discovery on 12 April 2002.
    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]
    1320.00
    2652.00

  • 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
    2295.0
    2319.5
    [m ]
    2
    2371.0
    2397.1
    [m ]
    3
    2398.0
    2412.2
    [m ]
    4
    2424.0
    2433.6
    [m ]
    5
    2435.0
    2437.8
    [m ]
    6
    2438.0
    2451.7
    [m ]
    7
    2452.0
    2455.4
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    94.2
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 2295-2300m
    Core photo at depth: 2300-2305m
    Core photo at depth: 2305-2310m
    Core photo at depth: 2310-2315m
    Core photo at depth: 2315-2319m
    2295-2300m
    2300-2305m
    2305-2310m
    2310-2315m
    2315-2319m
    Core photo at depth: 2371-2376m
    Core photo at depth: 2376-2381m
    Core photo at depth: 2381-2386m
    Core photo at depth: 2386-2391m
    Core photo at depth: 2391-2396m
    2371-2376m
    2376-2381m
    2381-2386m
    2386-2391m
    2391-2396m
    Core photo at depth: 2396-2397m
    Core photo at depth: 2398-2403m
    Core photo at depth: 2403-2408m
    Core photo at depth: 2408-2412m
    Core photo at depth: 2424-2429m
    2396-2397m
    2398-2403m
    2403-2408m
    2408-2412m
    2424-2429m
    Core photo at depth: 2429-2433m
    Core photo at depth: 2435-2437m
    Core photo at depth: 2438-2443m
    Core photo at depth: 2443-2448m
    Core photo at depth: 2448-2451m
    2429-2433m
    2435-2437m
    2438-2443m
    2443-2448m
    2448-2451m
    Core photo at depth: 2452-2455m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    2452-2455m

  • 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
    459.0
    36
    460.0
    0.00
    LOT
    SURF.COND.
    13 3/8
    1290.0
    17 1/2
    1315.0
    1.57
    LOT
    OPEN HOLE
    2652.0
    8 1/2
    2652.0
    0.00
    LOT

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    ECS HNGS CMR+
    2215
    2519
    FMI DSI GR
    0
    0
    FMI DSI GR
    473
    1974
    FMI DSI GR
    1289
    2478
    FMI DSI GR
    1940
    2620
    MDT DPS
    2295
    2332
    MDT PRE
    2295
    2535
    MDT SMP
    2375
    2464
    MWD - LWD MPT
    459
    1303
    MWD - LWD MPT
    1315
    2652
    PEX HRLA
    1292
    2650
    VSP GR
    1260
    2615

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.41

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    5.45

  • Documents – reported by the production licence (period for duty of secrecy expired)
    Documents – reported by the production licence (period for duty of secrecy expired)
    Document name
    Document format
    Document size [MB]
    .pdf
    6.87
    .PDF
    14.55

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    451
    1.03
    SEAWATER/PAC
    459
    1.03
    SEAWATER/PAC
    1303
    1.03
    SEAWATER/PAC
    1341
    1.37
    33.0
    KCL/GLYCOL/POLY
    1835
    1.35
    23.0
    KCL/GLYCOL/POLY
    1871
    1.35
    26.0
    KCL/GLYCOL/POLY