Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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sodir.no          Norsk
22.12.2024 - 01:25
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34/3-4 A

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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.
    34/3-4 A
    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.
    34/3-4
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    inline 5142 & crossline 3374
    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.
    BG Norge 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.
    1552-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.
    74
    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,
    27.11.2014
    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.
    13.02.2015
    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.
    13.02.2017
    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.
    13.02.2017
    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.
    22.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    406.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4535.0
    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).
    4343.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    31.2
    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.
    AMUNDSEN FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    61° 48' 7.42'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 52' 5.97'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6852301.14
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    493058.17
    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.
    7606

  • Wellbore history
    General
    Well 34/3-4 A was drilled to test the Jordbær Sørøst prospect on Tampen Spur in the Northern North Sea. The primary objective was to test the hydrocarbon potential in the Early Jurassic Cook formation.
    Operations and results
    On 27 November 2014 wildcat well 34/3-4 A was kicked off from below the 20" shoe set in 34/3-4 S at 1017 m. It was drilled with the semi-submersible installation Transocean Searcher to TD at 4535 m in the Early Jurassic Amundsen Formation. Problems with the cement jobs for the 13/3/8" and 9 7/8" casing cement jobs were experienced, otherwise no significant problem was encountered in the operations. The well was drilled with water based KCl/Glycol mud down to 2258 m and with Versatec oil based mud from 2258 m to TD.
    Sandstones of the Cook Formation were penetrated at 4370.5 m MD, (4179.8 m TVD). The Cook Formation had 113 m sand with a total N/G of 0.63 based on petrophysical evaluation. The sands were water saturated. The well section that was drilled water based did not have shows. In the oil based section the Cook Formation had good hydrocarbon odour in places but otherwise there were no shows above the oil base.
    No cores were cut and no fluid sample was taken.
    The well was permanently abandoned on 13 February 2015 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]
    1030.00
    4534.20

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1600.0
    [m]
    DC
    PETROSTR
    1610.0
    [m]
    DC
    PETROS
    1620.0
    [m]
    DC
    PETROS
    1630.0
    [m]
    DC
    PETROS
    1640.0
    [m]
    DC
    PETROS
    1650.0
    [m]
    DC
    PETROS
    1660.0
    [m]
    DC
    PETROS
    1670.0
    [m]
    DC
    PETROS
    1680.0
    [m]
    DC
    PETROS
    1690.0
    [m]
    DC
    PETROS
    1700.0
    [m]
    DC
    PETROS
    1710.0
    [m]
    DC
    PETROS
    1720.0
    [m]
    DC
    PETROS
    1730.0
    [m]
    DC
    PETROS
    1740.0
    [m]
    DC
    PETROS
    1750.0
    [m]
    DC
    PETROS
    1760.0
    [m]
    DC
    PETROS
    1770.0
    [m]
    DC
    PETROS
    1780.0
    [m]
    DC
    PETROS
    1790.0
    [m]
    DC
    PETROS
    1800.0
    [m]
    DC
    PETROS
    3900.0
    [m]
    DC
    PETROS
    3910.0
    [m]
    DC
    PETROS
    3920.0
    [m]
    DC
    PETROS
    3930.0
    [m]
    DC
    PETROS
    3940.0
    [m]
    DC
    PETROS
    3950.0
    [m]
    DC
    PETROS
    3960.0
    [m]
    DC
    PETROS
    3970.0
    [m]
    DC
    PETROS
    3975.0
    [m]
    DC
    PETROS
    3980.0
    [m]
    DC
    PETROS
    3985.0
    [m]
    DC
    PETROS
    3990.0
    [m]
    DC
    PETROS
    4000.0
    [m]
    DC
    PETROS
    4010.0
    [m]
    DC
    PETROS
    4030.0
    [m]
    DC
    PETROS
    4040.0
    [m]
    DC
    PETROS
    4050.0
    [m]
    DC
    PETROS
    4060.0
    [m]
    DC
    PETROS
    4070.0
    [m]
    DC
    PETROS
    4080.0
    [m]
    DC
    PETROS
    4090.0
    [m]
    DC
    PETROS
    4100.0
    [m]
    DC
    PETROS
    4115.0
    [m]
    DC
    PETROS
    4120.0
    [m]
    DC
    PETROS
    4130.0
    [m]
    DC
    PETROS
    4140.0
    [m]
    DC
    PETROS
    4150.0
    [m]
    DC
    PETROS
    4160.0
    [m]
    DC
    PETROS
    4170.0
    [m]
    DC
    PETROS
    4180.0
    [m]
    DC
    PETROS
    4190.0
    [m]
    DC
    PETROS
    4200.0
    [m]
    DC
    PETROS
    4210.0
    [m]
    DC
    PETROS
    4220.0
    [m]
    DC
    PETROS
    4230.0
    [m]
    DC
    PETROS
    4235.0
    [m]
    DC
    PETROS
    4242.5
    [m]
    DC
    PETROS
    4245.0
    [m]
    DC
    PETROS
    4250.0
    [m]
    DC
    PETROS
    4255.0
    [m]
    DC
    PETROS
    4260.0
    [m]
    DC
    PETROS
    4265.0
    [m]
    DC
    PETROS
    4270.0
    [m]
    DC
    PETROS
    4275.0
    [m]
    DC
    PETROS
    4280.0
    [m]
    DC
    PETROS
    4285.0
    [m]
    DC
    PETROS
    4290.0
    [m]
    DC
    PETROS
    4295.0
    [m]
    DC
    PETROS
    4300.0
    [m]
    DC
    PETROS
    4305.0
    [m]
    DC
    PETROS
    4310.0
    [m]
    DC
    PETROS
    4315.0
    [m]
    DC
    PETROS
    4320.0
    [m]
    DC
    PETROS
    4325.0
    [m]
    DC
    PETROS
    4330.0
    [m]
    DC
    PETROS
    4335.0
    [m]
    DC
    PETROS
    4340.0
    [m]
    DC
    PETROS
    4345.0
    [m]
    DC
    PETROS
    4350.0
    [m]
    DC
    PETROS
    4355.0
    [m]
    DC
    PETROS
    4360.0
    [m]
    DC
    PETROS
    4365.0
    [m]
    DC
    PETROS
    4370.0
    [m]
    DC
    PETROS
    4375.0
    [m]
    DC
    PETROS
    4377.5
    [m]
    DC
    PETROS
    4380.0
    [m]
    DC
    PETROS
    4385.0
    [m]
    DC
    PETROS
    4390.0
    [m]
    DC
    PETROS
    4395.0
    [m]
    DC
    PETROS
    4400.0
    [m]
    DC
    PETROS
    4402.5
    [m]
    DC
    PETROS
    4405.0
    [m]
    DC
    PETROS
    4407.5
    [m]
    DC
    PETROS
    4410.0
    [m]
    DC
    PETROS
    4415.0
    [m]
    DC
    PETROS
    4420.0
    [m]
    DC
    PETROS
    4425.0
    [m]
    DC
    PETROS
    4430.0
    [m]
    DC
    PETROS
    4435.0
    [m]
    DC
    PETROS
    4440.0
    [m]
    DC
    PETROS
    4445.0
    [m]
    DC
    PETROS
    4450.0
    [m]
    DC
    PETROS
    4455.0
    [m]
    DC
    PETROS
    4460.0
    [m]
    DC
    PETROS
    4462.5
    [m]
    DC
    PETROS
    4465.0
    [m]
    DC
    PETROS
    4467.5
    [m]
    DC
    PETROS
    4470.0
    [m]
    DC
    PETROS
    4475.0
    [m]
    DC
    PETROS
    4477.5
    [m]
    DC
    PETROS
    4480.0
    [m]
    DC
    PETROS
    4485.0
    [m]
    DC
    PETROS
    4490.0
    [m]
    DC
    PETROS
    4495.0
    [m]
    DC
    PETROS
    4500.0
    [m]
    DC
    PETROS
    4505.0
    [m]
    DC
    PETROS
    4510.0
    [m]
    DC
    PETROS
    4515.0
    [m]
    DC
    PETROS
    4520.0
    [m]
    DC
    PETROS
    4525.0
    [m]
    DC
    PETROS
    4530.0
    [m]
    DC
    PETROS
    4534.2
    [m]
    DC
    PETROS

  • Lithostratigraphy

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    LEH QT ECRD EDTC MSIP
    3834
    4232
    LWD - ARC
    524
    4238
    LWD - DIR
    428
    524
    LWD - ECO
    4240
    4535

  • 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
    518.8
    36
    524.0
    0.00
    SURF.COND.
    20
    1017.6
    26
    1023.0
    1.50
    FIT
    INTERM.
    13 3/8
    2252.0
    17 1/2
    2258.0
    1.80
    FIT
    INTERM.
    9 7/8
    4233.0
    12 1/4
    4238.0
    2.10
    FIT
    OPEN HOLE
    4535.0
    8 1/2
    4535.0
    0.00

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    1984
    1.39
    35.0
    KCl/Poly/Glycol
    2258
    1.42
    34.0
    Versatec
    2258
    1.41
    30.0
    KCl/Poly/Glycol
    2530
    1.42
    26.0
    Versatec
    3645
    1.60
    43.0
    Versatec
    4210
    1.84
    67.0
    Versatec
    4212
    1.70
    52.0
    Versatec
    4241
    1.84
    71.0
    Versatec
    4469
    1.84
    68.0
    Versatec