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

6608/10-7

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.
    6608/10-7
    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.
    6608/10-7
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    ST9301:inline 2448 & crossline2344
    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.
    Den norske stats oljeselskap a.s
    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.
    1000-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.
    55
    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,
    30.03.2001
    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.
    23.05.2001
    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.
    23.05.2003
    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.
    07.11.2005
    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.
    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.
    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.
    ÅRE FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    31.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    377.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2319.0
    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).
    2318.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    3.1
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    84
    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° 4' 41.5'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    8° 14' 43.28'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7329017.24
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    465853.10
    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.
    4273

  • Wellbore history
    General
    The main objective of well 6608/10-7 was to test the extent of hydrocarbons in Late to Early Jurassic sandstones in the Melke- and Åre Formation, down flanks of well 6608/10-6, and if possible prove fluid contacts. Another objective, originally designated to a possible sidetrack of well 6608/10-7, was to perform an interference test in the Åre Formation towards well 6608/10-6. A sidetrack was to be drilled if analysis of formation water samples confirmed high content of
    Barium. This would demand information about communication towards 6608/10-6 from a position further down flanks than the 6608/10-7 position.
    Operations and results
    Appraisal well 6608/10-7 was spudded with the semi-submersible installation Borgland Dolphin on 30 March 2001 and drilled to TD at 2319 m in Early Jurassic sediments of the Åre Formation. No shallow gas was observed by the ROV at the wellhead. The well was drilled with seawater and hi-vis sweeps down to 1315 m and with Aquadrill PAC/Glycol/KCL water base mud system from 1315 m to TD.
    Oil shows appeared at ca 1800 m (top Cromer Knoll Group) and disappeared below 2018 m (top Båt Group). Two reservoir zones were penetrated, a Melke Formation Sandstone member and the Åre Formation. A silty/sandy Not Formation was also encountered, but it did not have the same reservoir quality as the two previously mentioned. The sandstone sequence of the Melke Formation proved to be oil bearing. The main part of the oil bearing reservoir zone was cored. Oil was observed down to top Not Formation at 2007 m. No oil-water contact was encountered. Weak hydrocarbon shows were seen in core chips from the Not Formation. The Åre Formation proved to be water filled up to its top at 2018 m. The water samples proved to have a Barium content lower than the limit set for requiring the sidetrack to be drilled. The observed formation tops were not in accordance with the prognosis. The difference between the prognosis and the observations for Tertiary and Cretaceous formation tops seem to vary a bit. Typically, the Tertiary and Cretaceous formation tops, as well as the base Cretaceous unconformity were encountered deeper than prognosed. The top of the Melke Formation sandstone sequences, the Not Formation and the Åre Formation were encountered shallower than prognosed, but within the given uncertainties.
    A total of 8 cores were cut in the reservoirs from 1955 m to 2101.5 m. An MDT oil sample was taken at 1967.8 m in the Melke Formation sandstone unit, while MDT water samples were taken at 2155.5 m and 2052.2 m in the Åre Formation.
    The well was permanently abandoned on 23 May 2001 as an oil appraisal well.
    Testing
    Pressure memory gauges had been installed in well bore 6608/10-6, in November 2000. The gauges were retrieved in August 2001. A water injection test was conducted in 6608/10-7 on 7 May 2001 and the pressure response was measured in well bore 6608/10-6 R2. Pressure response was seen within 24 hours after the injection started, proving good communication over the 1520 m between the two wells. The pressure gauges also recorded temperature, and after eight and a half months the temperature, at 1854 m, had reached 64.1 deg C. Interestingly, but not important for the test, the temperature increased steadily throughout the period. The temperature increase over the last 230 days of the period was only 0.25 deg C.
    After the water injection test in Åre the Melke Formation sand was perforated from 1950 m to 1980 m for a production test. The initial pressure in Melke when initiating the test was 10 bar above the logged MDT pressure. This had to be caused by the injection test in Åre, making the results from the production test invalid.

  • 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
    2318.00

  • 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
    1955.0
    1966.1
    [m ]
    2
    1973.5
    1986.9
    [m ]
    3
    1987.0
    1993.7
    [m ]
    4
    1993.5
    1998.7
    [m ]
    5
    1998.3
    2024.2
    [m ]
    6
    2024.2
    2052.2
    [m ]
    7
    2052.2
    2074.0
    [m ]
    8
    2074.0
    2101.0
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    139.1
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1955.3
    [m]
    C
    WESTLB
    1957.7
    [m]
    C
    WESTLB
    1961.6
    [m]
    C
    WESTLB
    1964.6
    [m]
    C
    WESTLB
    1973.7
    [m]
    C
    WESTLB
    1977.7
    [m]
    C
    WESTLB
    1982.5
    [m]
    C
    WESTLB
    1985.5
    [m]
    C
    WESTLB
    1987.4
    [m]
    C
    WESTLB
    1990.5
    [m]
    C
    WESTLB
    1992.9
    [m]
    C
    WESTLB
    1993.6
    [m]
    C
    WESTLB
    1996.7
    [m]
    C
    WESTLB
    1998.4
    [m]
    C
    WESTLB
    1998.6
    [m]
    C
    WESTLB
    2001.1
    [m]
    C
    WESTLB
    2003.7
    [m]
    C
    WESTLB
    2006.5
    [m]
    C
    WESTLB
    2009.9
    [m]
    C
    WESTLB
    2012.5
    [m]
    C
    WESTLB
    2013.5
    [m]
    C
    WESTLB
    2016.5
    [m]
    C
    WESTLB
    2017.7
    [m]
    C
    WESTLB
    2018.8
    [m]
    C
    WESTLB
    2019.7
    [m]
    C
    WESTLB
    2022.9
    [m]
    C
    WESTLB
    2024.4
    [m]
    C
    WESTLB
    2030.0
    [m]
    C
    WESTLB
    2034.7
    [m]
    C
    WESTLB
    2039.0
    [m]
    C
    WESTLB
    2042.7
    [m]
    C
    WESTLB
    2043.3
    [m]
    C
    WESTLB
    2048.7
    [m]
    C
    WESTLB
    2055.0
    [m]
    C
    WESTLB
    2057.8
    [m]
    C
    WESTLB
    2059.7
    [m]
    C
    WESTLB
    2060.5
    [m]
    C
    WESTLB
    2065.3
    [m]
    C
    WESTLB
    2069.0
    [m]
    C
    WESTLB
    2072.9
    [m]
    C
    WESTLB
    2074.3
    [m]
    C
    WESTLB
    2079.4
    [m]
    C
    WESTLB
    2083.9
    [m]
    C
    WESTLB
    2086.4
    [m]
    C
    WESTLB
    2089.5
    [m]
    C
    WESTLB
    2089.7
    [m]
    C
    WESTLB
    2095.5
    [m]
    C
    WESTLB
    2100.4
    [m]
    C
    WESTLB

  • 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
    OIL
    30.04.2001 - 02:26
    YES

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.29

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    3.55

  • 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
    8.37
    .PDF
    2.70

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CMR ECS HNGS
    1790
    2310
    FMI DSI GR
    780
    2317
    MDT GR
    1808
    1810
    MDT GR
    1951
    2248
    MDT GR
    1967
    1967
    MDT GR
    2155
    2155
    MWD - DGR EWD PWD
    465
    1315
    MWD - DGR EWR PWD BAT
    1319
    1955
    MWD - DGR EWR PWD BAT
    2102
    2319
    MWD - DGR EWR-4 PWD
    1975
    2102
    MWD - PWD
    1276
    1319
    PEX HRLA
    1305
    2320
    ZVSP
    800
    2310

  • 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
    468.0
    36
    470.0
    0.00
    LOT
    SURF.COND.
    13 3/8
    1305.0
    17 1/2
    1310.0
    1.56
    LOT
    LINER
    7
    2319.0
    8 1/2
    2319.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    424
    1.03
    SEAWATER/BENT.
    487
    1.03
    SEAWATER/BENT.
    920
    1.03
    SEAWATER/BENT.
    1315
    1.03
    SEAWATER/BENT.
    1640
    1.30
    32.0
    KCL/GLYCOL/PAC
    1955
    1.26
    30.0
    KCL/GLYCOL/PAC
    2319
    1.26
    22.0
    KCL/GLYCOL/PAC

  • 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
    0.27