Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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sodir.no          Norsk
22.11.2024 - 09:09
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35/10-3

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  • General information
    General information
    Attribute Value
    Wellbore name
    Official name of wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    35/10-3
    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).
    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.
    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.
    35/10-3
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    ST 9303- INLINE 536 & CROSSLINE 2436
    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.
    950-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.
    22
    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,
    23.06.1999
    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.
    14.07.1999
    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.
    14.07.2001
    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.
    18.12.2002
    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.
    24.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    363.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2250.0
    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).
    2247.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    4.4
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    65
    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 CRETACEOUS
    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.
    JORSALFARE FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    61° 2' 47.96'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    3° 7' 40.22'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6768151.37
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    506904.47
    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.
    3719

  • Wellbore history
    General
    Production License 173, block 35/10, is located north-northwest of the Troll, approximately 80 km off-shore Western Norway. Well 35/10-3 is the third well drilled within the PL 173 licence area. The objective of the well was to test the hydrocarbon potential of Paleocene deep marine sandstones (Hermod Formation) of the Sele Formation in the southern part of block 35/10, known as the the Graben Fill prospect. The reservoir was expected to consist of two deep marine fans, stacked on each other.
    Operations and results
    Wildcat well 35/10-3 was spudded 23 June 1999 with the semi-submersible installation "Transocean Arctic". First attempt to spud failed due to boulders at 427 m. The installation was moved 20 m and after a successful second spud it was drilled to a total depth of 2250 m in the Late Cretaceous Jorsalfare Formation. The well was drilled with bentonite/PAC down to 655 m and KCl polymer mud (Ultidrill) from 655 m to TD. No shallow gas was encountered. A class 2 warning (over-pressured shallow gas) was given for a sand layer prognosed at 675 m. The Hermod Formation was penetrated at 1948 m and consisted of 35 m sandstone, as prognosed. The sandstone was water filled. Weak direct fluorescence and a few grams with cut fluorescence and increase in heavy components in the background gas was described. The prognosed lower fan proved to consist of claystone. No conventional cores were cut and no fluid samples were taken.
    The well was permanently plugged and abandoned as a dry well on 14 July 1999.
    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]
    660.00
    2250.00

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    660.0
    [m]
    DC
    RRI
    700.0
    [m]
    DC
    RRI
    720.0
    [m]
    DC
    RRI
    740.0
    [m]
    DC
    RRI
    760.0
    [m]
    DC
    RRI
    820.0
    [m]
    DC
    RRI
    840.0
    [m]
    DC
    RRI
    860.0
    [m]
    DC
    RRI
    880.0
    [m]
    DC
    RRI
    900.0
    [m]
    DC
    RRI
    920.0
    [m]
    DC
    RRI
    940.0
    [m]
    DC
    RRI
    960.0
    [m]
    DC
    RRI
    980.0
    [m]
    DC
    RRI
    1000.0
    [m]
    DC
    RRI
    1020.0
    [m]
    DC
    RRI
    1040.0
    [m]
    DC
    RRI
    1060.0
    [m]
    DC
    RRI
    1080.0
    [m]
    DC
    RRI
    1100.0
    [m]
    DC
    RRI
    1120.0
    [m]
    DC
    RRI
    1140.0
    [m]
    DC
    RRI
    1160.0
    [m]
    DC
    RRI
    1180.0
    [m]
    DC
    RRI
    1200.0
    [m]
    DC
    RRI
    1220.0
    [m]
    DC
    RRI
    1240.0
    [m]
    DC
    RRI
    1260.0
    [m]
    DC
    RRI
    1280.0
    [m]
    DC
    RRI
    1300.0
    [m]
    DC
    RRI
    1320.0
    [m]
    DC
    RRI
    1340.0
    [m]
    DC
    RRI
    1360.0
    [m]
    DC
    RRI
    1380.0
    [m]
    DC
    RRI
    1400.0
    [m]
    DC
    RRI
    1420.0
    [m]
    DC
    RRI
    1440.0
    [m]
    DC
    RRI
    1460.0
    [m]
    DC
    RRI
    1480.0
    [m]
    DC
    RRI
    1500.0
    [m]
    DC
    RRI
    1520.0
    [m]
    DC
    RRI
    1540.0
    [m]
    DC
    RRI
    1560.0
    [m]
    DC
    RRI
    1580.0
    [m]
    DC
    RRI
    1600.0
    [m]
    DC
    RRI
    1620.0
    [m]
    DC
    RRI
    1640.0
    [m]
    DC
    RRI
    1660.0
    [m]
    DC
    RRI
    1680.0
    [m]
    DC
    RRI
    1700.0
    [m]
    DC
    RRI
    1720.0
    [m]
    DC
    RRI
    1740.0
    [m]
    DC
    RRI
    1760.0
    [m]
    DC
    RRI
    1780.0
    [m]
    DC
    RRI
    1800.0
    [m]
    DC
    RRI
    1821.0
    [m]
    DC
    RRI
    1842.0
    [m]
    DC
    RRI
    1860.0
    [m]
    DC
    RRI
    1866.0
    [m]
    DC
    RRI
    1872.0
    [m]
    DC
    RRI
    1878.0
    [m]
    DC
    RRI
    1884.0
    [m]
    DC
    RRI
    1890.0
    [m]
    DC
    RRI
    1893.0
    [m]
    DC
    RRI
    1896.0
    [m]
    DC
    RRI
    1899.0
    [m]
    DC
    RRI
    1902.0
    [m]
    DC
    RRI
    1905.0
    [m]
    DC
    RRI
    1908.0
    [m]
    DC
    RRI
    1911.0
    [m]
    DC
    RRI
    1914.0
    [m]
    DC
    RRI
    1917.0
    [m]
    DC
    RRI
    1929.0
    [m]
    DC
    RRI
    1935.0
    [m]
    DC
    RRI
    1938.0
    [m]
    DC
    RRI
    1941.0
    [m]
    DC
    RRI
    1944.0
    [m]
    DC
    RRI
    1947.0
    [m]
    DC
    RRI
    1950.0
    [m]
    DC
    RRI
    1953.0
    [m]
    DC
    RRI
    1956.0
    [m]
    DC
    RRI
    1959.0
    [m]
    DC
    RRI
    1962.0
    [m]
    DC
    RRI
    1965.0
    [m]
    DC
    RRI
    1968.0
    [m]
    DC
    RRI
    1971.0
    [m]
    DC
    RRI
    1974.0
    [m]
    DC
    RRI
    1977.0
    [m]
    DC
    RRI
    1980.0
    [m]
    DC
    RRI
    1983.0
    [m]
    DC
    RRI
    1986.0
    [m]
    DC
    RRI
    1989.0
    [m]
    DC
    RRI
    1992.0
    [m]
    DC
    RRI
    1995.0
    [m]
    DC
    RRI
    1998.0
    [m]
    DC
    RRI
    2001.0
    [m]
    DC
    RRI
    2004.0
    [m]
    DC
    RRI
    2007.0
    [m]
    DC
    RRI
    2010.0
    [m]
    DC
    RRI
    2013.0
    [m]
    DC
    RRI
    2016.0
    [m]
    DC
    RRI
    2019.0
    [m]
    DC
    RRI
    2022.0
    [m]
    DC
    RRI
    2025.0
    [m]
    DC
    RRI
    2035.0
    [m]
    DC
    RRI
    2045.0
    [m]
    DC
    RRI
    2055.0
    [m]
    DC
    RRI
    2065.0
    [m]
    DC
    RRI
    2075.0
    [m]
    DC
    RRI
    2085.0
    [m]
    DC
    RRI
    2095.0
    [m]
    DC
    RRI
    2105.0
    [m]
    DC
    RRI
    2115.0
    [m]
    DC
    RRI
    2125.0
    [m]
    DC
    RRI
    2132.0
    [m]
    DC
    RRI
    2135.0
    [m]
    DC
    RRI
    2138.0
    [m]
    DC
    RRI
    2141.0
    [m]
    DC
    RRI
    2145.0
    [m]
    DC
    RRI
    2150.0
    [m]
    DC
    RRI
    2153.0
    [m]
    DC
    RRI
    2160.0
    [m]
    DC
    RRI
    2170.0
    [m]
    DC
    RRI
    2180.0
    [m]
    DC
    RRI
    2190.0
    [m]
    DC
    RRI
    2195.0
    [m]
    DC
    RRI
    2200.0
    [m]
    DC
    RRI
    2205.0
    [m]
    DC
    RRI
    2210.0
    [m]
    DC
    RRI
    2215.0
    [m]
    DC
    RRI
    2220.0
    [m]
    DC
    RRI
    2230.0
    [m]
    DC
    RRI
    2235.0
    [m]
    DC
    RRI
    2240.0
    [m]
    DC
    RRI
    2245.0
    [m]
    DC
    RRI
    2250.0
    [m]
    DC
    RRI

  • Lithostratigraphy
    Lithostratigraphy
    Top depth [mMD RKB]
    Lithostrat. unit
    387
    922
    937
    1247
    1269
    1881
    1881
    1948
    1984
    2030
    2193
    2199
    2199

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.16

  • 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
    1.60
    .pdf
    34.35

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    FMT GR
    1950
    1983
    HDIL MAC ZDL CND DSL TTRM
    1807
    2248
    MWD - MPR
    1807
    2250
    MWD - MPR-L
    468
    1818
    VSP GR
    1195
    2170

  • 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
    INTERM.
    20
    645.0
    26
    645.0
    1.27
    LOT
    INTERM.
    13 3/8
    1807.0
    17 1/2
    1807.0
    1.66
    LOT
    OPEN HOLE
    2250.0
    12 1/4
    2250.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    655
    1.03
    BENTONITE/FW
    1256
    1.21
    17.0
    KCL/GLYCOL/PAC
    1494
    1.21
    DUMMY
    1645
    1.25
    21.0
    KCL/GLYCOL/PAC
    1818
    1.30
    22.0
    KCL/GLYCOL/PAC
    1940
    1.37
    31.0
    KCL/GLYCOL/PAC
    1950
    1.37
    31.0
    KCL/GLYCOL/PAC
    1950
    1.37
    31.0
    KCL/GLYCOL/PAC
    2250
    1.37
    31.0
    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
    0.22