Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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22.11.2024 - 09:09
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34/7-33

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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.
    34/7-33
    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
    Multilateral
    Indicator telling if the parent well is multilateral, meaning it has more than one branch radiating from the main borehole. Example of legal values: YES, NO. See also Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    NO
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    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.
    34/7-33
    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.
    StatoilHydro ASA
    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.
    1193-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.
    61
    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,
    16.08.2008
    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.
    15.10.2008
    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.
    15.10.2010
    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.
    15.10.2010
    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
    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.
    233.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2615.0
    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).
    2611.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    9.6
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    86
    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.
    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° 19' 2.5'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 5' 46.4'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6798634.03
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    451605.51
    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.
    5917

  • Wellbore history
    General
    Well 34/7-33 was drilled in the Vigdis/Tordis area on Tampen Spur in the Northern North Sea. The primary objective was to test the potential for oil in the sandstones of the Brent Group in the M5 Sør prospect. The secondary target of the well was to acquire data to clarify the potential of the Sele /Lista interval, if reservoir with hydrocarbon was present and to acquire data over the Utsira Formation Sandstones in order to evaluate the potential for future injection of produced water from the Tordis Field sub-sea separator.
    Operations and results
    An 8 1/2" pilot hole, well 34/7-U-17, was drilled to evaluate for shallow gas and to log the Utsira Formation. Based on MWD/LWD and ROV indications shallow gas was observed in intervals from 336 to 340 m and between 548 to 550 m. No indications of shallow gas were however observed in the subsequent 36" and 26" hole in well 34/7-33.
    Wildcat well 34/7-33 was spudded with the semi-submersible installation Ocean Vanguard on 16 August 2008 and drilled to TD at 2615 m in the Early Jurassic Drake Formation. Due to flash setting of the cement when cementing the 9 5/8" casing the well was side-tracked (34/7-33 T2), with KOP at 1592 m. The well was drilled with spud mud down to 1053 m, with KCl/polymer mud from 1053 m to 1690 m, with HP/WBM mud from 1690 m to 2260 m, and with KCL/Polymer/glycol mud from 2260 m to TD.
    The well penetrated rocks of Quaternary, Tertiary, Cretaceous, and Jurassic age. The well proved approximately 10 meters oil bearing sandstones in the Lista Formation. Cores were taken and good shows were recorded in the sand beds in these cores. Well results suggest that only 1 of the 10 meters sandy interval had properties as a producible reservoir. Gas peaks with a full range of C1 to C5 were recorded in the Balder and Lista Formation, and in the underlying Shetland Group increased gas levels (2-3%) with C1 to C5 were recorded in the interval 2150 to 2220 m. The well further proved, unexpectedly, the presence of Early Cretaceous and Heather age sands resting directly on the Brent Group Ness Formation. The uppermost Tarbert Formation of the Brent Group was not seen in the 34/7-33 T2 well. The reservoir sections in the Brent Group had excellent reservoir properties, as expected, but were water wet with only weak shows at 2392 to 2402 m and 2506 to 2522 m.
    Two cores were cut before sidetracking from 1772 m to 1825 m in the Lista Formation. MDT pressure points were attempted before sidetracking in the Lista Formation but only three were obtained due to the thin sandstones encountered. A reliable gradient could not be established. Oil samples were taken at 1801.8 m but due to high drawdown the fluids obtained were not representative. A Mini DST was also attempted in the thin Lista Formation sands, but was not successful. A second MDT run in the sidetrack in the Viking and Brent groups obtained high quality pressure points. Several pressure barriers were indicated by these data. Good water samples were obtained at 2333 m.
    The well was permanently abandoned on 15 October as a well with good shows.
    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]
    1060.00
    2250.00

  • 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
    1772.0
    1798.0
    [m ]
    2
    1798.0
    1825.0
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    53.0
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • 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
    315.0
    36
    315.0
    0.00
    LOT
    SURF.COND.
    20
    1053.0
    26
    1053.0
    1.53
    LOT
    INTERM.
    13 3/8
    1715.0
    17 1/2
    1720.0
    1.64
    LOT
    LINER
    9 5/8
    2261.0
    12 1/4
    2261.0
    1.69
    LOT
    OPEN HOLE
    2615.0
    8 1/2
    2615.0
    0.00
    LOT

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    MDT GR
    1790
    1850
    MDT GR
    2325
    2538
    MWD LWD - ARC
    1059
    1720
    MWD LWD - GVR ARC
    1720
    1772
    MWD LWD - POWERPULSE ARC
    1583
    2271
    MWD LWD - VSONIC6
    255
    1110
    PEX HRLA DSI
    1420
    2245
    PEX HRLA DSI
    1555
    2607
    VSP
    955
    2560

  • Lithostratigraphy

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    1062
    1.39
    22.0
    KCl/Polymer/Glycol
    1200
    1.39
    24.0
    KCl/Polymer/Glycol
    1430
    1.50
    30.0
    KCl/Polymer/Glycol
    1581
    1.50
    32.0
    KCl/Polymer/Glycol
    1616
    1.50
    31.0
    HPWBM
    1704
    1.50
    30.0
    HPWBM
    1720
    1.52
    32.0
    KCl/Polymer/Glycol
    1772
    1.50
    29.0
    KCl/Polymer/Glycol
    1786
    1.50
    30.0
    HPWBM
    2108
    1.50
    37.0
    HPWBM
    2138
    1.52
    34.0
    HPWBM
    2255
    1.52
    33.0
    HPWBM
    2264
    1.50
    36.0
    HPWBM
    2269
    1.58
    26.0
    KCl/Polymer/Glycol
    2569
    1.58
    24.0
    KCl/Polymer/Glycol
    2615
    1.58
    25.0
    KCl/Polymer/Glycol