Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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36/7-2

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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.
    36/7-2
    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
    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
    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.
    36/7-2
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    NH 9205 - 113 A & SP. 625
    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.
    Norsk Hydro Produksjon 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.
    869-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.
    21
    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,
    02.09.1997
    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.
    22.09.1997
    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.
    22.09.1999
    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.
    23.05.2006
    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.
    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.
    YES
    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.
    LATE 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.
    FENSFJORD FM
    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.
    269.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    1435.0
    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).
    1435.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    1.8
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    34
    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.
    PRE-DEVONIAN
    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.
    BASEMENT
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    61° 18' 23.5'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    4° 19' 47'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6797817.45
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    571225.20
    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.
    2990

  • Wellbore history
    General
    Well 36/7-2 was drilled on the Øygarden Fault Complex, ca 14 km west of the outer skerries of Bulandet in Sogn og Fjordane county. The primary target were the Late Jurassic Sognefjord and the Upper Jurassic Fensfjord formations.
    Operations and results
    Wildcat well 36/7-2 was spudded with the semi-submersible installation West Vanguard on 2 September 1997 and drilled to TD at 1435 m in basement rock. An anchor test was performed after setting the 13 3/8" casing shoe. Anchor no. 2 and 3 failed the test to 180 ton and slipped at 170 ton. Piggyback anchors were set on anchor no. 2, while main anchor no. 3 was lost. Fishing for the anchor chain was delayed 47.5 hrs due to bad weather. The anchor chain was retrieved and the anchor reset with two piggy backs. Both anchors then stood a successful test. The well was drilled with seawater and hi-vis pills down to 591 m and with ANCO 2000 from 591 m to TD.
    The well discovered heavily biodegraded oil in the Middle Jurassic deltaic sandstone reservoir of the Fensfjord Formation. The overlying Sognefjord Formation sands were tight and contained no hydrocarbons. A 32.5 m oil column was proven from 931.5 to ca 964.0 m. The exact level of the oil-water contact could not be determined as it was in a shaley zone. Oil shows on cuttings were recorded from 915 m down to 1045 m. The reservoir zone of the Fensfjord Formation was divided into two units, from which only the upper had good reservoir properties.
    No conventional cores were cut, but 60 sidewall cores were taken from 603 to 1408 m with a recovery of 56 samples. The MDT tool was run and 23 good pressure points were acquired in addition to a fluid sample at 934.5 m.
    The well was completed on 22 September 1997 as an oil discovery.
    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]
    595.00
    1435.00

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    603.0
    [m]
    SWC
    RRI
    615.0
    [m]
    SWC
    RRI
    623.0
    [m]
    SWC
    RRI
    639.0
    [m]
    SWC
    RRI
    653.5
    [m]
    SWC
    RRI
    665.0
    [m]
    SWC
    RRI
    685.0
    [m]
    SWC
    RRI
    695.0
    [m]
    DC
    RRI
    705.0
    [m]
    SWC
    RRI
    722.0
    [m]
    SWC
    RRI
    730.0
    [m]
    DC
    RRI
    744.0
    [m]
    SWC
    RRI
    755.0
    [m]
    DC
    RRI
    768.0
    [m]
    SWC
    RRI
    775.0
    [m]
    DC
    RRI
    785.0
    [m]
    DC
    RRI
    795.0
    [m]
    SWC
    RRI
    805.0
    [m]
    DC
    RRI
    817.5
    [m]
    SWC
    RRI
    834.0
    [m]
    DC
    RRI
    847.0
    [m]
    DC
    RRI
    859.0
    [m]
    DC
    RRI
    867.0
    [m]
    DC
    RRI
    870.0
    [m]
    DC
    RRI
    887.0
    [m]
    DC
    RRI
    900.0
    [m]
    DC
    RRI
    908.0
    [m]
    DC
    RRI
    920.0
    [m]
    DC
    RRI
    935.0
    [m]
    DC
    RRI
    945.0
    [m]
    DC
    RRI
    955.0
    [m]
    DC
    RRI
    969.5
    [m]
    SWC
    RRI
    975.0
    [m]
    DC
    RRI
    987.5
    [m]
    SWC
    RRI
    995.0
    [m]
    DC
    RRI
    1005.0
    [m]
    DC
    RRI
    1017.0
    [m]
    SWC
    RRI
    1037.0
    [m]
    SWC
    RRI
    1045.0
    [m]
    DC
    RRI
    1055.0
    [m]
    DC
    RRI
    1065.0
    [m]
    DC
    RRI
    1075.0
    [m]
    DC
    RRI
    1090.0
    [m]
    DC
    RRI
    1100.0
    [m]
    DC
    RRI
    1110.0
    [m]
    DC
    RRI
    1124.0
    [m]
    DC
    RRI
    1135.0
    [m]
    DC
    RRI
    1142.0
    [m]
    DC
    RRI
    1155.0
    [m]
    DC
    RRI
    1165.0
    [m]
    DC
    RRI
    1175.0
    [m]
    DC
    RRI
    1190.0
    [m]
    DC
    RRI
    1195.0
    [m]
    DC
    RRI
    1210.0
    [m]
    DC
    RRI
    1225.0
    [m]
    DC
    RRI
    1231.0
    [m]
    DC
    RRI
    1245.0
    [m]
    DC
    RRI
    1255.0
    [m]
    DC
    RRI
    1267.0
    [m]
    SWC
    RRI
    1280.0
    [m]
    DC
    RRI
    1290.0
    [m]
    DC
    RRI
    1300.0
    [m]
    SWC
    RRI
    1310.0
    [m]
    DC
    RRI
    1325.0
    [m]
    DC
    RRI
    1335.0
    [m]
    SWC
    RRI
    1340.0
    [m]
    DC
    RRI
    1352.0
    [m]
    SWC
    RRI
    1370.0
    [m]
    DC
    RRI
    1387.0
    [m]
    SWC
    RRI
    1390.0
    [m]
    DC
    RRI
    1400.0
    [m]
    DC
    RRI
    1408.0
    [m]
    SWC
    RRI
    1435.0
    [m]
    DC
    RRI

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.24

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    11.89

  • 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
    8.87

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    ARRAY SONIC GR AMS
    586
    1431
    CST GR AMS
    603
    1408
    MDT GR AMS
    918
    1100
    MDT GR AMS
    934
    1375
    MWD - GR RES DIR
    291
    1435
    PEX AMS
    291
    1433
    VSP GR
    586
    1430

  • 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
    340.0
    36
    355.0
    0.00
    LOT
    SURF.COND.
    13 3/8
    587.0
    17 1/2
    591.0
    1.48
    LOT
    OPEN HOLE
    925.0
    12 1/4
    925.0
    0.00
    LOT
    OPEN HOLE
    1435.0
    8 1/2
    1435.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    592
    1.05
    WATER BASED
    1117
    1.15
    20.0
    WATER BASED
    1435
    1.16
    18.0
    WATER BASED

  • 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
    0.16