Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
21.11.2024 - 01:28
Time of last synchronization with Norwegian Offshore Directorate's internal systems

10/7-1

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.
    10/7-1
    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
    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.
    NORTH SEA
    Well name
    Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    10/7-1
    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.
    Esso Exploration and Production Norway 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.
    735-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.
    33
    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,
    28.06.1992
    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.
    30.07.1992
    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.
    30.07.1994
    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.
    22.04.2005
    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.
    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.
    DRY
    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
    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.
    86.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    1890.0
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    67
    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.
    LATE PERMIAN
    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.
    ZECHSTEIN GP
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    57° 28' 23.3'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    5° 3' 33.21'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6372070.68
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    623496.64
    UTM zone
    Universal Transverse Mercator zone. Examples of legal values: 31, 32, 33, 34.
    31
    NPDID wellbore
    Norwegian Offshore Directorate's unique id for the wellbore.
    1972

  • Wellbore history
    General
    Well 10/7-1 is located at the southeastern end of the Egersund Basin in the North Sea. The objective of the well was to test the Tott prospect, a faulted anticline over a salt wall. The Middle Jurassic Bryne formation was the primary objective. A thin Sandnes formation sandstone overlying the Bryne was interpreted to be possible at the drilled location.
    Operations and results
    Wildcat well 10/7-1 was spudded with the semi-submersible installation Sonat Arcade Frontier on 28 June 1992 and drilled to TD at 1890 m in the Late Permian Zechstein Group. The well was drilled with seawater and gel down to 793 m and with KCl/polymer mud from 793 m to TD.
    Good reservoir quality sandstones were encountered in both the Sandnes and Bryne formations of the Vestland group. The top of the Sandnes formation was penetrated at 1539 m; top of the Bryne at 1632 m. Total thickness of the Vestland group is 297 m. From drill cuttings, fair to good visible porosity was observed in fine to coarse-grained sandstones throughout the Vestland group. Reservoir quality is good, with a net sand/gross thickness ratio of 54.5% using a 12% porosity cut-off. Using the same cut-off value the average porosity of the reservoir sandstones in the Vestland group is 23.3%. Bathonian age sediments (Bryne Formation) rested directly on Late Permian Zechstein salt at 1836 m. Occasional, spotty shows were observed in cuttings from the Sandnes and Bryne Formations. These marginal shows were interpreted to be sourced from in-situ carbonaceous material and not as migrated hydrocarbons. Analysis of the wire line logs and wire line pressure data clearly indicated that the sandstones of the Vestland group were water bearing. Organic geochemical analyses showed Total Organic Carbon (TOC) from 1.0 to 3.19 % and Hydrogen Index (HI) from 79 to 224 mg HC/g TOC in the Late Jurassic shales, which was classified as a poor oil and gas source. Associated with coals in the Vestland group were gas prone sediments with TOC values ranging from 1.64 - 6.14% and HI values of 118 to 223. The well was found immature for oil and gas generation; maximum vitrinite reflectance, recorded near TD, was 0.45 %Ro. Extractable organic matter contained low to modest amounts of immature hydrocarbons associated with local shales and coals, consistent with the trace shows recorded during drilling.
    One conventional core was cut in the Sandnes formation, from 1561 to 1566.5 m, where the core jammed. The recovered core (3.95 m) consisted of sandstone with a thin claystone/shale bed at the base. Shows were not observed in the core. Core analysis indicated generally fair to good porosity and permeability. FMT pressures also indicated fair to good permeability throughout the Vestland group. No fluid sample was taken.
    The well was permanently abandoned on 30 July 1992 as a dry hole.
    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]
    800.00
    1890.00

  • 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
    1561.0
    1565.2
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    4.2
    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
    145.0
    36
    147.0
    0.00
    LOT
    INTERM.
    13 3/8
    779.0
    17 1/2
    793.0
    0.00
    LOT
    OPEN HOLE
    1890.0
    12 1/4
    1890.0
    0.00
    LOT

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL
    110
    656
    CNL ZDL GR SP CAL
    777
    1888
    DIPMETER
    777
    1888
    DLL MLL AC GR SP CAL
    777
    1888
    FMT GR
    1542
    1823
    MWD EQW
    150
    786
    SONAN
    120
    656
    SWC
    875
    1886
    TEMPERATURE
    110
    665
    VSP ZO
    400
    1845

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.26

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    2.32
    pdf
    4.82

  • 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
    1.36
    pdf
    7.24
    pdf
    17.96

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    115
    1.04
    WATER BASED
    132
    1.04
    WATER BASED
    147
    1.04
    WATER BASED
    147
    1.04
    WATER BASED
    505
    1.04
    WATER BASED
    666
    1.20
    38.0
    WATER BASED
    793
    1.11
    WATER BASED
    793
    1.04
    WATER BASED
    804
    1.11
    10.0
    WATER BASED
    889
    1.14
    10.0
    WATER BASED
    987
    1.14
    10.0
    WATER BASED
    1070
    1.14
    10.0
    WATER BASED
    1230
    1.16
    11.0
    WATER BASED
    1230
    1.16
    8.0
    WATER BASED
    1288
    1.26
    36.0
    WATER BASED
    1379
    1.29
    42.0
    WATER BASED
    1541
    1.33
    41.0
    WATER BASED
    1565
    1.37
    44.0
    WATER BASED
    1681
    1.37
    45.0
    WATER BASED
    1842
    1.37
    43.0
    WATER BASED
    1890
    1.37
    43.0
    WATER BASED

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    800.0
    [m]
    DC
    RRI
    800.0
    [m]
    DC
    810.0
    [m]
    DC
    RRI
    820.0
    [m]
    DC
    RRI
    830.0
    [m]
    DC
    RRI
    830.0
    [m]
    DC
    860.0
    [m]
    DC
    875.0
    [m]
    DC
    890.0
    [m]
    DC
    920.0
    [m]
    DC
    950.0
    [m]
    DC
    975.0
    [m]
    DC
    1010.0
    [m]
    DC
    1029.0
    [m]
    DC
    1084.0
    [m]
    DC
    1130.0
    [m]
    DC
    1160.0
    [m]
    DC
    1186.5
    [m]
    SWC
    1220.0
    [m]
    DC
    1230.0
    [m]
    DC
    1250.0
    [m]
    DC
    1280.0
    [m]
    DC
    1290.0
    [m]
    DC
    1320.0
    [m]
    DC
    1333.0
    [m]
    SWC
    1350.0
    [m]
    DC
    1370.0
    [m]
    DC
    1378.0
    [m]
    SWC
    1400.0
    [m]
    DC
    1436.5
    [m]
    SWC
    1440.0
    [m]
    DC
    GEUS
    1460.0
    [m]
    DC
    GEUS
    1462.0
    [m]
    DC
    1480.0
    [m]
    DC
    GEUS
    1490.0
    [m]
    DC
    1500.0
    [m]
    DC
    1500.0
    [m]
    DC
    GEUS
    1510.0
    [m]
    DC
    1520.0
    [m]
    DC
    GEUS
    1535.0
    [m]
    SWC
    1540.0
    [m]
    DC
    1540.0
    [m]
    DC
    GEUS
    1545.0
    [m]
    SWC
    1550.0
    [m]
    DC
    1560.0
    [m]
    DC
    GEUS
    1561.0
    [m]
    DC
    1561.6
    [m]
    C
    1565.0
    [m]
    DC
    1565.2
    [m]
    C
    1581.0
    [m]
    DC
    GEUS
    1587.0
    [m]
    DC
    1600.0
    [m]
    DC
    1600.0
    [m]
    DC
    GEUS
    1618.0
    [m]
    DC
    GEUS
    1619.0
    [m]
    SWC
    1630.0
    [m]
    DC
    1640.0
    [m]
    DC
    GEUS
    1650.0
    [m]
    DC
    1660.0
    [m]
    DC
    GEUS
    1660.0
    [m]
    DC
    GEUS
    1670.0
    [m]
    DC
    1680.0
    [m]
    DC
    GEUS
    1690.0
    [m]
    DC
    1700.0
    [m]
    DC
    GEUS
    1710.0
    [m]
    DC
    1715.0
    [m]
    SWC
    1720.0
    [m]
    DC
    GEUS
    1730.0
    [m]
    DC
    1733.0
    [m]
    SWC
    1740.0
    [m]
    DC
    GEUS
    1750.0
    [m]
    DC
    1759.0
    [m]
    DC
    1760.0
    [m]
    DC
    GEUS
    1760.0
    [m]
    DC
    GEUS
    1765.0
    [m]
    DC
    1775.0
    [m]
    DC
    1780.0
    [m]
    DC
    1780.0
    [m]
    C
    1780.0
    [m]
    DC
    1800.0
    [m]
    DC
    GEUS
    1805.0
    [m]
    DC
    1805.0
    [m]
    DC
    1820.0
    [m]
    DC
    GEUS
    1820.0
    [m]
    DC
    GEUS
    1825.0
    [m]
    SWC
    1830.0
    [m]
    C
    1830.0
    [m]
    DC
    GEUS
    1840.0
    [m]
    C
    1850.0
    [m]
    SWC
    1850.0
    [m]
    DC
    1865.0
    [m]
    C
    1877.0
    [m]
    SWC
    1886.0
    [m]
    SWC
    1890.0
    [m]
    DC
    1890.0
    [m]
    C