Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
22.11.2024 - 09:09
Time of last synchronization with Norwegian Offshore Directorate's internal systems

7120/8-3

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.
    7120/8-3
    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
    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.
    BARENTS 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.
    7120/8-3
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    513 - 138 SP 590
    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.
    368-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.
    48
    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,
    07.04.1983
    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.
    24.05.1983
    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.
    24.05.1985
    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.
    29.06.2004
    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.
    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.
    SHOWS
    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.
    22.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    280.5
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2335.0
    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).
    2325.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    1.9
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    58
    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.
    NORDMELA FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    71° 27' 48.77'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    20° 36' 9.47'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7929358.33
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    485899.85
    UTM zone
    Universal Transverse Mercator zone. Examples of legal values: 31, 32, 33, 34.
    34
    NPDID wellbore
    Norwegian Offshore Directorate's unique id for the wellbore.
    9

  • Wellbore history
    General
    The purpose of appraisal well 7120/8-3 was to test the extension of the Askeladden North structure in the northeast direction. The primary target was sandstones of Early to Middle Jurassic age.
    Operations and results
    The well was spudded with the semi-submersible rig West Vanguard on 7 April 1983 and drilled to TD at 2335 in Early Jurassic rocks of the Nordmela Formation. Two cores were cut in the Middle to Lower Jurassic sequence. No major problems occurred during drilling. The well was drilled water based with spud mud down to 671 m and with gypsum/polymer mud from 671 m to TD.
    Shows were recorded on cores and cuttings over the interval 2192 m to 2286 m. The Jurassic reservoir interval was found to be below the gas/water contact known from well 7120/8-1, and thus water bearing. Two cores were cut in the interval 2198 m to 2234.8 m. No fluid samples were taken.
    The well was permanently abandoned on 24 May 1983 as a dry well.
    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]
    370.00
    2331.00

  • 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
    2198.0
    2216.0
    [m ]
    2
    2216.0
    2234.0
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    36.0
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 2198-2202m
    Core photo at depth: 2203-2207m
    Core photo at depth: 2208-2212m
    Core photo at depth: 2213-2215m
    Core photo at depth: 2216-2220m
    2198-2202m
    2203-2207m
    2208-2212m
    2213-2215m
    2216-2220m
    Core photo at depth: 2221-2225m
    Core photo at depth: 2226-2230m
    Core photo at depth: 2231-2233m
    Core photo at depth:  
    Core photo at depth:  
    2221-2225m
    2226-2230m
    2231-2233m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    380.0
    [m]
    DC
    PAS
    400.0
    [m]
    DC
    PAS
    420.0
    [m]
    DC
    PAS
    440.0
    [m]
    DC
    PAS
    460.0
    [m]
    DC
    PAS
    480.0
    [m]
    DC
    PAS
    500.0
    [m]
    DC
    PAS
    520.0
    [m]
    DC
    PAS
    540.0
    [m]
    DC
    PAS
    560.0
    [m]
    DC
    PAS
    580.0
    [m]
    DC
    PAS
    600.0
    [m]
    DC
    PAS
    620.0
    [m]
    DC
    PAS
    640.0
    [m]
    DC
    PAS
    660.0
    [m]
    DC
    PAS
    680.0
    [m]
    DC
    PAS
    700.0
    [m]
    DC
    PAS
    720.0
    [m]
    DC
    PAS
    740.0
    [m]
    DC
    PAS
    760.0
    [m]
    DC
    PAS
    780.0
    [m]
    DC
    PAS
    800.0
    [m]
    DC
    PAS
    820.0
    [m]
    DC
    PAS
    840.0
    [m]
    DC
    PAS
    860.0
    [m]
    DC
    PAS
    880.0
    [m]
    DC
    PAS
    900.0
    [m]
    DC
    PAS
    920.0
    [m]
    DC
    PAS
    940.0
    [m]
    DC
    PAS
    960.0
    [m]
    DC
    PAS
    980.0
    [m]
    DC
    PAS
    1000.0
    [m]
    DC
    PAS
    1020.0
    [m]
    DC
    PAS
    1020.0
    [m]
    DC
    1040.0
    [m]
    DC
    PAS
    1060.0
    [m]
    DC
    1080.0
    [m]
    DC
    PAS
    1090.0
    [m]
    DC
    1140.0
    [m]
    DC
    1140.0
    [m]
    DC
    PAS
    1160.0
    [m]
    DC
    PAS
    1180.0
    [m]
    DC
    PAS
    1190.0
    [m]
    DC
    PAS
    1212.0
    [m]
    DC
    PAS
    1227.0
    [m]
    DC
    PAS
    1239.0
    [m]
    DC
    1242.0
    [m]
    DC
    PAS
    1257.0
    [m]
    DC
    PAS
    1272.0
    [m]
    DC
    PAS
    1287.0
    [m]
    DC
    PAS
    1302.0
    [m]
    DC
    PAS
    1317.0
    [m]
    DC
    PAS
    1332.0
    [m]
    DC
    PAS
    1341.0
    [m]
    DC
    1347.0
    [m]
    DC
    PAS
    1362.0
    [m]
    DC
    PAS
    1392.0
    [m]
    DC
    PAS
    1407.0
    [m]
    DC
    PAS
    1422.0
    [m]
    DC
    PAS
    1440.0
    [m]
    DC
    PAS
    1440.0
    [m]
    DC
    1452.0
    [m]
    DC
    PAS
    1467.0
    [m]
    DC
    PAS
    1482.0
    [m]
    DC
    PAS
    1497.0
    [m]
    DC
    PAS
    1512.0
    [m]
    DC
    PAS
    1527.0
    [m]
    DC
    PAS
    1539.0
    [m]
    DC
    1542.0
    [m]
    DC
    PAS
    1557.0
    [m]
    DC
    PAS
    1585.0
    [m]
    SWC
    PAS
    1602.0
    [m]
    DC
    PAS
    1632.0
    [m]
    DC
    PAS
    1641.0
    [m]
    DC
    1647.0
    [m]
    DC
    PAS
    1662.0
    [m]
    DC
    PAS
    1677.0
    [m]
    DC
    PAS
    1692.0
    [m]
    DC
    PAS
    1707.0
    [m]
    DC
    PAS
    1722.0
    [m]
    SWC
    PAS
    1737.0
    [m]
    DC
    PAS
    1740.0
    [m]
    DC
    1755.0
    [m]
    SWC
    PAS
    1767.0
    [m]
    DC
    PAS
    1782.0
    [m]
    DC
    PAS
    1797.0
    [m]
    DC
    PAS
    1812.0
    [m]
    DC
    PAS
    1827.0
    [m]
    DC
    PAS
    1839.0
    [m]
    DC
    1842.0
    [m]
    DC
    PAS
    1857.0
    [m]
    DC
    PAS
    1873.0
    [m]
    SWC
    PAS
    1887.0
    [m]
    DC
    PAS
    1902.0
    [m]
    DC
    PAS
    1917.0
    [m]
    DC
    PAS
    1932.0
    [m]
    DC
    PAS
    1941.0
    [m]
    DC
    1947.0
    [m]
    DC
    PAS
    1962.0
    [m]
    DC
    PAS
    1977.0
    [m]
    DC
    PAS
    1992.0
    [m]
    DC
    PAS
    2007.0
    [m]
    DC
    PAS
    2037.0
    [m]
    DC
    PAS
    2040.0
    [m]
    DC
    2052.0
    [m]
    DC
    PAS
    2075.0
    [m]
    SWC
    PAS
    2079.0
    [m]
    DC
    2082.0
    [m]
    DC
    PAS
    2097.0
    [m]
    DC
    PAS
    2115.0
    [m]
    SWC
    PAS
    2127.0
    [m]
    DC
    PAS
    2142.0
    [m]
    DC
    PAS
    2157.0
    [m]
    DC
    PAS
    2178.0
    [m]
    SWC
    PAS
    2187.0
    [m]
    DC
    PAS
    2198.7
    [m]
    C
    PAS
    2200.7
    [m]
    C
    PAS
    2207.4
    [m]
    C
    PAS
    2220.1
    [m]
    C
    PAS
    2229.8
    [m]
    C
    PAS
    2235.0
    [m]
    DC
    PAS
    2247.0
    [m]
    DC
    PAS
    2262.0
    [m]
    DC
    PAS
    2277.0
    [m]
    DC
    PAS
    2292.0
    [m]
    DC
    PAS
    2307.0
    [m]
    DC
    PAS
    2331.0
    [m]
    DC
    PAS

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.36

  • 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
    6.54
    pdf
    0.93

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL VDL
    305
    1497
    CST
    1548
    2286
    CST
    2208
    2330
    HDT
    671
    1071
    HDT
    1498
    2334
    ISF SON GR SP CAL
    365
    1511
    ISF SON MSFL GR SP CAL
    1498
    2333
    LDT CNL GR
    1498
    2334
    LDT GR CAL
    365
    1513
    RFT
    2193
    2304
    VSP
    338
    2330

  • 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
    366.0
    36
    366.0
    0.00
    LOT
    SURF.COND.
    20
    671.0
    26
    686.0
    1.67
    LOT
    INTERM.
    13 3/8
    1500.0
    17 1/2
    1515.0
    1.65
    LOT
    OPEN HOLE
    2335.0
    12 1/2
    2335.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    368
    0.00
    spud mud
    686
    1.06
    60.0
    44.0
    water mud
    1013
    1.16
    44.0
    21.0
    water mud
    1515
    1.31
    55.0
    18.0
    water mud
    1870
    1.34
    48.0
    16.0
    water mud
    2216
    1.38
    53.0
    15.0
    water mud
    2313
    1.38
    55.0
    16.0
    water mud

  • 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
    0.26