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

7121/9-1

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.
    7121/9-1
    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
    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.
    BARENTS SEA
    Well name
    Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    7121/9-1
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    DG0901/DG09M1 PSTM inline 1896 & crossline 2808
    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.
    DONG E&P Norge AS
    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.
    1381-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.
    46
    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,
    15.10.2011
    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.
    29.11.2011
    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.
    10.08.2013
    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.
    10.08.2013
    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
    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.
    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.
    40.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    310.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2458.0
    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).
    2458.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    2.9
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    85
    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.
    MIDDLE 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.
    KAPP TOSCANA GP
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    71° 15' 13.94'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    21° 42' 41.75'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7906075.02
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    525524.99
    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.
    6728

  • Wellbore history
    General
    Well 7121/9-1 was drilled on the Zapffe prospect in the southern part of the Hammerfest Basin, ca 19 km west of the Goliat Field. The objective was to prove petroleum in Late Jurassic and Early Cretaceous reservoir rocks (Knurr and Hekkingen formations).
    Operations and results
    Wildcat well 7121/9-1 was spudded with the semi-submersible installation Aker Barents on and drilled to TD at 2458 m in Middle Jurassic sediments of the Kapp Toscana Group. A 9 7/8" pilot hole was drilled from 413 m to 855 m to check for shallow gas. No shallow gas was seen. Total rig time for the well was 47.8 days, of which 15.6 days (32.6%) were counted as non-productive time. The two main causes for the NPT were problems with cement at the 13 3/8"casing shoe (6.8 days) and WOW (3.2 days). The well was drilled with seawater and bentonite down to 855 m and with Glydril mud from 855 m to TD.
    The well encountered top Knurr Formation at 1809 m with considerably thinner reservoir rocks and with poorer reservoir quality than expected. The Knurr Formation contained a hot-shale in the lower part with high gamma ray and up to 9 % TOC from 2027 to 2034 m. The Hekkingen Formation was encountered at 2018 m with the typical high gamma ray/high TOC Alge Member at its base, from 2292 m to 2318 m. There was no reservoir rock in the Hekkingen formation. Weak oil shows (weak, mostly blue-white direct and cut fluorescence) in sidewall cores from sandstone in the Knurr Formation and shales in the Hekkingen Formation.
    No conventional cores were cut and no wire line fluid samples were taken.
    The well was permanently abandoned on 29 November 2011 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]
    860.00
    2458.00

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    860.0
    [m]
    DC
    FUGRO
    880.0
    [m]
    DC
    FUGRO
    900.0
    [m]
    DC
    FUGRO
    920.0
    [m]
    DC
    FUGRO
    940.0
    [m]
    DC
    FUGRO
    960.0
    [m]
    DC
    FUGRO
    980.0
    [m]
    DC
    FUGRO
    1000.0
    [m]
    DC
    FUGRO
    1020.0
    [m]
    DC
    FUGRO
    1040.0
    [m]
    DC
    FUGRO
    1060.0
    [m]
    DC
    FUGRO
    1080.0
    [m]
    DC
    FUGRO
    1100.0
    [m]
    DC
    FUGRO
    1120.0
    [m]
    DC
    FUGRO
    1140.0
    [m]
    DC
    FUGRO
    1160.0
    [m]
    DC
    FUGRO
    1180.0
    [m]
    DC
    FUGRO
    1200.0
    [m]
    DC
    FUGRO
    1220.0
    [m]
    DC
    FUGRO
    1260.0
    [m]
    DC
    FUGRO
    1280.0
    [m]
    DC
    FUGRO
    1300.0
    [m]
    DC
    FUGRO
    1320.0
    [m]
    DC
    FUGRO
    1340.0
    [m]
    DC
    FUGRO
    1360.0
    [m]
    DC
    FUGRO
    1380.0
    [m]
    DC
    FUGRO
    1400.0
    [m]
    DC
    FUGRO
    1420.0
    [m]
    DC
    FUGRO
    1440.0
    [m]
    DC
    FUGRO
    1460.0
    [m]
    DC
    FUGRO
    1480.0
    [m]
    DC
    FUGRO
    1500.0
    [m]
    DC
    FUGRO
    1520.0
    [m]
    DC
    FUGRO
    1540.0
    [m]
    DC
    FUGRO
    1560.0
    [m]
    DC
    FUGRO
    1580.0
    [m]
    DC
    FUGRO
    1600.0
    [m]
    DC
    FUGRO
    1620.0
    [m]
    DC
    FUGRO
    1640.0
    [m]
    DC
    FUGRO
    1660.0
    [m]
    DC
    FUGRO
    1680.0
    [m]
    DC
    FUGRO
    1700.0
    [m]
    DC
    FUGRO
    1720.0
    [m]
    DC
    FUGRO
    1740.0
    [m]
    DC
    FUGRO
    1760.0
    [m]
    DC
    FUGRO
    1780.0
    [m]
    DC
    FUGRO
    1800.0
    [m]
    DC
    FUGRO
    1820.0
    [m]
    DC
    FUGRO
    1830.0
    [m]
    DC
    FUGRO
    1840.0
    [m]
    DC
    FUGRO
    1850.0
    [m]
    DC
    FUGRO
    1864.0
    [m]
    DC
    FUGRO
    1872.0
    [m]
    DC
    FUGRO
    1888.0
    [m]
    DC
    FUGRO
    1900.0
    [m]
    DC
    FUGRO
    1912.0
    [m]
    DC
    FUGRO
    1948.0
    [m]
    DC
    FUGRO
    1960.0
    [m]
    DC
    FUGRO
    1972.0
    [m]
    DC
    FUGRO
    1984.0
    [m]
    DC
    FUGRO
    1993.0
    [m]
    DC
    FUGRO
    2011.0
    [m]
    DC
    FUGRO
    2020.0
    [m]
    DC
    FUGRO
    2031.0
    [m]
    SWC
    FUGRO
    2034.0
    [m]
    SWC
    FUGRO
    2047.0
    [m]
    DC
    FUGRO
    2056.0
    [m]
    DC
    FUGRO
    2074.0
    [m]
    DC
    FUGRO
    2090.0
    [m]
    SWC
    FUGRO
    2107.0
    [m]
    DC
    FUGRO
    2119.0
    [m]
    DC
    FUGRO
    2128.0
    [m]
    DC
    FUGRO
    2155.0
    [m]
    SWC
    FUGRO
    2164.0
    [m]
    DC
    FUGRO
    2173.0
    [m]
    DC
    FUGRO
    2191.0
    [m]
    DC
    FUGRO
    2198.0
    [m]
    SWC
    FUGRO
    2205.0
    [m]
    SWC
    FUGRO
    2227.0
    [m]
    DC
    FUGRO
    2240.0
    [m]
    SWC
    FUGRO
    2254.0
    [m]
    DC
    FUGRO
    2264.0
    [m]
    SWC
    FUGRO
    2281.0
    [m]
    DC
    FUGRO
    2294.7
    [m]
    SWC
    FUGRO
    2299.0
    [m]
    SWC
    FUGRO
    2306.0
    [m]
    SWC
    FUGRO
    2310.0
    [m]
    SWC
    FUGRO
    2326.0
    [m]
    DC
    FUGRO
    2344.0
    [m]
    DC
    FUGRO
    2353.0
    [m]
    DC
    FUGRO
    2362.0
    [m]
    DC
    FUGRO
    2371.0
    [m]
    DC
    FUGRO
    2380.0
    [m]
    DC
    FUGRO
    2398.0
    [m]
    DC
    FUGRO
    2407.0
    [m]
    DC
    FUGRO
    2416.0
    [m]
    DC
    FUGRO
    2425.0
    [m]
    DC
    FUGRO
    2434.0
    [m]
    DC
    FUGRO
    2443.0
    [m]
    DC
    FUGRO
    2452.0
    [m]
    DC
    FUGRO

  • Lithostratigraphy

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    MSCT
    1975
    2440
    MSIP HRLA PEX HNGS
    350
    2458
    MWD LWD - PP ARCVIS
    413
    855
    MWD LWD - PP ARCVIS SONVIS
    855
    1837
    MWD LWD - TELE
    350
    413
    MWD LWD - TELE ARCVIS SONVIS
    413
    855
    VSI4
    1249
    2444
    VSP
    418
    1295

  • 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
    36
    410.0
    42
    412.0
    0.00
    LOT
    SURF.COND.
    20
    849.0
    26
    855.0
    0.00
    LOT
    PILOT HOLE
    855.0
    9 7/8
    855.0
    0.00
    LOT
    INTERM.
    13 3/8
    1298.5
    17 1/2
    1305.0
    1.73
    LOT
    INTERM.
    9 5/8
    1832.0
    12 1/4
    1837.0
    1.65
    LOT
    OPEN HOLE
    2458.0
    8 1/2
    2458.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    862
    1.24
    16.0
    Glydril WBM
    1250
    1.24
    19.0
    Glydril WBM
    1305
    1.29
    21.0
    Glydril
    1308
    1.34
    23.0
    Glydril
    1311
    1.34
    22.0
    Glydril
    2458
    1.36
    27.0
    Glydril
    2458
    1.34
    26.0
    Glydril