Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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23.07.2024 - 01:26
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34/7-32

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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.
    34/7-32
    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.
    34/7-32
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    SG 9701 4240/6554
    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.
    1015-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.
    19
    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,
    09.10.2001
    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.
    27.10.2001
    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.
    27.10.2003
    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.
    06.01.2014
    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.
    25.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    297.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2651.0
    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).
    2651.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    1.2
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    79
    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.
    DRAKE FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    61° 26' 50.26'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 3' 16.19'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6813138.62
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    449581.05
    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.
    4423
  • Wellbore history

    General
    Well 34/7-32 was drilled on the Xenon structure on Tampen Spur ca 2 km west of the Snorre Field in the North Sea. The objective was to test the hydrocarbon potential in the Middle Jurassic Brent Group. The well was planned and drilled as a "smart well" i.e. with a reduced data acquisition programme if dry.
    Operations and results
    Wildcat well 34/7-32 was spudded with the semi-submersible installation on 9 October 2001 and drilled to TD at 2651 m in Middle Jurassic rocks of the Drake Formation. A 17 1/2" pilot hole was drilled from 384 m to 700 m to check for shallow gas. No shallow gas was observed. The well was drilled with sea water and hi-vis pills down to 1385 m and with Versavert oil based mud from 1385 m to TD. No significant problem was encountered in the operations. Total rig time from spud to P&A was 20 days, including two days wait-on-weather.
    The sandstones in the Brent Group proved to be water bearing, with a water gradient of 1.00 g/cm3. No shows were observed.
    No cores were cut. Wire line logging consisted of one run (MDT-GR-ECRD) from 2616 m to 2538 m. Seven pressure points were acquired, no fluid sample was taken.
    The well was permanently abandoned on 27 October 2001 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]
    1390.00
    2649.00
  • Palynological slides at the Norwegian Offshore Directorate

    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1390.0
    [m]
    DC
    RRI
    1410.0
    [m]
    DC
    RRI
    1430.0
    [m]
    DC
    RRI
    1450.0
    [m]
    DC
    RRI
    1470.0
    [m]
    DC
    RRI
    1490.0
    [m]
    DC
    RRI
    1510.0
    [m]
    DC
    RRI
    1530.0
    [m]
    DC
    RRI
    1550.0
    [m]
    DC
    RRI
    1570.0
    [m]
    DC
    RRI
    1590.0
    [m]
    DC
    RRI
    1610.0
    [m]
    DC
    RRI
    1630.0
    [m]
    DC
    RRI
    1650.0
    [m]
    DC
    RRI
    1670.0
    [m]
    DC
    RRI
    1690.0
    [m]
    DC
    RRI
    1710.0
    [m]
    DC
    RRI
    1730.0
    [m]
    DC
    RRI
    1750.0
    [m]
    DC
    RRI
    1770.0
    [m]
    DC
    RRI
    1790.0
    [m]
    DC
    RRI
    1810.0
    [m]
    DC
    RRI
    1830.0
    [m]
    DC
    RRI
    1850.0
    [m]
    DC
    RRI
    1870.0
    [m]
    DC
    RRI
    1890.0
    [m]
    DC
    RRI
    1910.0
    [m]
    DC
    RRI
    1930.0
    [m]
    DC
    RRI
    1950.0
    [m]
    DC
    RRI
    1970.0
    [m]
    DC
    RRI
    1990.0
    [m]
    DC
    RRI
    2010.0
    [m]
    DC
    RRI
    2030.0
    [m]
    DC
    RRI
    2050.0
    [m]
    DC
    RRI
    2070.0
    [m]
    DC
    RRI
    2090.0
    [m]
    DC
    RRI
    2110.0
    [m]
    DC
    RRI
    2130.0
    [m]
    DC
    RRI
    2170.0
    [m]
    DC
    RRI
    2190.0
    [m]
    DC
    RRI
    2210.0
    [m]
    DC
    RRI
    2230.0
    [m]
    DC
    RRI
    2250.0
    [m]
    DC
    RRI
    2270.0
    [m]
    DC
    RRI
    2290.0
    [m]
    DC
    RRI
    2310.0
    [m]
    DC
    RRI
    2330.0
    [m]
    DC
    RRI
    2350.0
    [m]
    DC
    RRI
    2370.0
    [m]
    DC
    RRI
    2390.0
    [m]
    DC
    RRI
    2410.0
    [m]
    DC
    RRI
    2430.0
    [m]
    DC
    RRI
    2451.0
    [m]
    DC
    RRI
    2454.0
    [m]
    DC
    RRI
    2457.0
    [m]
    DC
    RRI
    2460.0
    [m]
    DC
    RRI
    2463.0
    [m]
    DC
    RRI
    2466.0
    [m]
    DC
    RRI
    2469.0
    [m]
    DC
    RRI
    2472.0
    [m]
    DC
    RRI
    2475.0
    [m]
    DC
    RRI
    2478.0
    [m]
    DC
    RRI
    2481.0
    [m]
    DC
    RRI
    2484.0
    [m]
    DC
    RRI
    2487.0
    [m]
    DC
    RRI
    2490.0
    [m]
    DC
    RRI
    2493.0
    [m]
    DC
    RRI
    2496.0
    [m]
    DC
    RRI
    2499.0
    [m]
    DC
    RRI
    2502.0
    [m]
    DC
    RRI
    2505.0
    [m]
    DC
    RRI
    2508.0
    [m]
    DC
    RRI
    2511.0
    [m]
    DC
    RRI
    2514.0
    [m]
    DC
    RRI
    2517.0
    [m]
    DC
    RRI
    2520.0
    [m]
    DC
    RRI
    2523.0
    [m]
    DC
    RRI
    2526.0
    [m]
    DC
    RRI
    2529.0
    [m]
    DC
    RRI
    2532.0
    [m]
    DC
    RRI
    2535.0
    [m]
    DC
    RRI
    2538.0
    [m]
    DC
    RRI
    2541.0
    [m]
    DC
    RRI
    2544.0
    [m]
    DC
    RRI
    2547.0
    [m]
    DC
    RRI
    2550.0
    [m]
    DC
    RRI
    2553.0
    [m]
    DC
    RRI
    2556.0
    [m]
    DC
    RRI
    2559.0
    [m]
    DC
    RRI
    2562.0
    [m]
    DC
    RRI
    2568.0
    [m]
    DC
    RRI
    2571.0
    [m]
    DC
    RRI
    2574.0
    [m]
    DC
    RRI
    2577.0
    [m]
    DC
    RRI
    2580.0
    [m]
    DC
    RRI
    2583.0
    [m]
    DC
    RRI
    2586.0
    [m]
    DC
    RRI
    2589.0
    [m]
    DC
    RRI
    2592.0
    [m]
    DC
    RRI
    2595.0
    [m]
    DC
    RRI
    2598.0
    [m]
    DC
    RRI
    2601.0
    [m]
    DC
    RRI
    2604.0
    [m]
    DC
    RRI
    2607.0
    [m]
    DC
    RRI
    2610.0
    [m]
    DC
    RRI
    2613.0
    [m]
    DC
    RRI
    2616.0
    [m]
    DC
    RRI
    2619.0
    [m]
    DC
    RRI
    2622.0
    [m]
    DC
    RRI
    2625.0
    [m]
    DC
    RRI
    2628.0
    [m]
    DC
    RRI
    2631.0
    [m]
    DC
    RRI
    2634.0
    [m]
    DC
    RRI
    2637.0
    [m]
    DC
    RRI
    2640.0
    [m]
    DC
    RRI
    2643.0
    [m]
    DC
    RRI
    2646.0
    [m]
    DC
    RRI
    2649.0
    [m]
    DC
    RRI
  • Lithostratigraphy

    Lithostratigraphy
    Top depth [mMD RKB]
    Lithostrat. unit
    322
    1090
    1102
    1689
    1689
    1732
    1871
    2527
    2527
    2535
    2535
    2557
    2636
    2636
  • 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
    6.27
    .PDF
    0.89
  • Logs

    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    MDT GR ECRD
    2538
    2616
    MWD - MPR LITE
    378
    2651
  • 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
    381.0
    36
    384.0
    0.00
    LOT
    PILOT HOLE
    700.0
    9 5/8
    700.0
    0.00
    LOT
    SURF.COND.
    13 3/8
    1378.0
    17 1/2
    1385.0
    1.62
    LOT
    OPEN HOLE
    2651.0
    9 1/2
    2651.0
    0.00
    LOT
  • Drilling mud

    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    381
    1.03
    CMC/SEAWATER
    700
    1.03
    CMC/SEAWATER
    962
    1.03
    BENTONITE/FW
    1385
    1.25
    BENTONITE/FW
    2535
    1.48
    27.0
    VERSAVERT
    2651
    1.48
    27.0
    VERSAVERT
  • 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