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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34/2-2 R

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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.
    34/2-2 R
    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
    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.
    34/2-2
    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.
    Amoco Norway Oil Company
    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.
    268-L2
    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.
    148
    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,
    12.12.1980
    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.
    08.05.1981
    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.
    08.05.1983
    Plugged and abondon date
    Date when the P&A-operations of the wellbore was finished, as reported by the operator to the Norwegian Offshore Directorate throught DDRS (Daily Drilling Reporting System). Only applied once pr. wellhead/surface location.
    08.05.1981
    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.
    11.02.2005
    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.
    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.
    26.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    386.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4074.0
    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).
    4067.6
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    11
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    120
    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 TRIASSIC
    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.
    STATFJORD GP
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    61° 46' 16.83'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 33' 11.38'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6848952.90
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    476419.52
    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.
    497

  • Wellbore history
    General
    Exploration well 34/2-2 is located a northwestern part of the Tampen Spur area. It was intended to be the first well to test the reflections below the Base Cretaceous (Kimmeridgian) Unconformity on a seismically defined, northerly trending west-northwest dipping fault block. The well was located near the apex of the structure at the Base Cretaceous level, but down-dip with respect to deeper stratigraphy. Primary targets were the Middle Jurassic Brent Formation and the Early Jurassic/Triassic Statfjord Formation. Secondary targets were possible Early Tertiary and Late Jurassic sandstones. Planned TD was 4300 m Sub Sea.
    Operations and results
    Well 34/2-2 R was spudded with the semi-submersible installation Sedco 703 on 12 December after the first entry 34/2-2 had been abandoned for technical reasons. The well was drilled to TD at 4074 m in the Late Triassic Statfjord Formation, Raude Member. Bad weather conditions during wintertime delayed the drilling progress on many occasions. While drilling the 36" hole section some problems were encountered due to boulder beds. An abnormally high wave hit the rig on 16 January, damaging the living quarters. The rig had to be shut down for repairs for eleven days. Otherwise, drilling of the sedimentary sequence below the 30" casing to TD did not cause major problems. The well was drilled with spud mud/hi-vis pills down to 499 m, with CMC and bentonite from 499 m to 810 m, and with lignosulphonate mud from 810 m to TD.
    The Brent Formation was not developed in the well and the reservoir conditions in the Statfjord Formations were found to be poorer than expected. No indications of hydrocarbon accumulations were seen. Trace shows were recorded in the Cretaceous in sandstone stringers from 2405 m to 2700 m, in siltstones from 2903 m to 3000 m, and in sandstones from 3200 m to 3282.5 m. From 3282.5 m to 3297.5 m there was a good show in a limestone bed. No oil shows were reported from the Jurassic sequences. The Late Jurassic Draupne Formation was not found in this well and organic geochemical analyses did not reveal any sequence with significant source potential throughout the well. The analyses did however confirm some intervals with migrant hydrocarbons in the Cretaceous. One conventional core was cut in the interval 3665 m to 3677 m in the Cook Formation. No fluid sample was taken.
    The well was permanently abandoned as a dry well with weak shows on 8 May 1981.
    Testing
    No drill stem test was performed.

  • 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
    3665.0
    3675.2
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    10.2
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 3665-3668m
    Core photo at depth: 3668-3671m
    Core photo at depth: 3671-3674m
    Core photo at depth: 3674-3675m
    Core photo at depth: 3665-3666m
    3665-3668m
    3668-3671m
    3671-3674m
    3674-3675m
    3665-3666m
    Core photo at depth: 3670-3670m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    3670-3670m

  • 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
    491.5
    36
    499.0
    0.00
    LOT
    SURF.COND.
    20
    800.0
    26
    810.0
    1.51
    LOT
    INTERM.
    13 3/8
    2014.0
    17 1/2
    2023.0
    1.74
    LOT
    INTERM.
    9 5/8
    3190.0
    12 1/4
    3200.0
    1.94
    LOT
    OPEN HOLE
    4074.0
    8 1/2
    4074.0
    0.00
    LOT

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL VDL GR CCL
    400
    2000
    CBL VDL GR CCL
    1000
    3167
    CBL VDL GR CCL
    1120
    3193
    DLL MSFL CAL GR
    3190
    4070
    DLL MSFL CAL GR SP
    2300
    3201
    FDC CNL CAL GR
    2014
    4070
    HDT CAL
    2014
    3200
    HDT CAL
    3190
    3840
    ISF LSS GR SP
    374
    4070
    VSP
    386
    3313

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.62

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.98
    pdf
    3.04
    pdf
    2.03
    pdf
    0.12

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    831
    1.07
    water based
    1375
    1.22
    46.0
    15.0
    water based
    1803
    1.28
    48.0
    21.0
    water based
    2023
    1.37
    47.0
    22.0
    water based
    3056
    1.55
    46.0
    29.0
    water based
    3418
    1.55
    50.0
    25.0
    water based
    3838
    1.55
    51.0
    31.0
    water based
    4040
    1.63
    52.0
    31.0
    water based