Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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22.12.2024 - 01:25
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34/4-3

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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.
    34/4-3
    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
    Well name
    Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    34/4-3
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    SG 8020 - 409 SP 580
    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.
    Saga Petroleum 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.
    306-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.
    166
    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,
    16.10.1981
    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.
    30.03.1982
    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.
    30.03.1984
    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.
    01.07.2004
    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.
    366.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4460.0
    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).
    4457.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    5
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    127
    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.
    LUNDE FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    61° 36' 32.95'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 7' 34.42'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6831114.85
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    453647.63
    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.
    423

  • Wellbore history
    General
    Exploration well 34/4-3 is located in the Marulk Basin north-northwest of the Snorre Field. It was drilled as the third well on the Gamma Structure and had a wedge structure between the Base Cretaceous Unconformity and the Late Jurassic Unconformity as primary target. Secondary objectives were to penetrate the Brent Equivalent and the Statfjord formation. The well is located on the downthrown side of a NE-SW trending major fault, and the sealing nature of this fault was critical for a closure of the reservoir.
    Operations and results
    Wildcat well 34/4-3 was spudded with the semi-submersible installation Dyvi Alpha on 16 October 1981 after waiting on location for two weeks due to bad weather. The 26" section was drilled with a 21 1/4" BOP installed but after pulling the riser and the BOP a 26" bit was run in the hole since the underreamer did not perform. Drilling of the 17 1/2" section was delayed by nearly two weeks due to the 18 3/4" BOP not meeting requirements. During drilling of the 12 1/4" section electrical problems on the draw works as well as mud pump breakdowns and high pressures was experienced. Drilling the 8 1/2" section included 4 core runs, killing a water/methane kick at 3555 m, changing leaking seals on riser and two intermediate log runs. TD was reached at 4460 m in Late Triassic sediments. The well was drilled with seawater/bentonite/gel down to 516 m, with gel/gypsum from 512 m to 1019 m, with gypsum/polymer from 1019 m to 2209 m, and with lignosulfonate mud from 2209 m to TD.
    A methane gas/water kick occurred at 3550 m when the first Late Jurassic sandstone stringer was entered, giving 21 % total gas. A more continuous Late Jurassic sand was drilled into at 3565 m. Two cores (18 m) were cut in this 27 m thick sandstone sequence. The cores consist of shallow marine laminated shale/silt/sandstone. The sandstone is grey, very fine to fine grained with average porosity 10%, permeability maximum 40 mD and water bearing.
    A second Late Jurassic sandstone was drilled through between 3704 -3788 m. The sandstone is white, fine to coarse grained, poor sorted and poor porosity, no shows. Minor shows are reported from the Late Jurassic and the basal part of the Cretaceous, occurring from 3524 to 3716 m. Sandstones of core 1 and the limestone in Cromer Knoll Group generally have no stain, but a very weak to weak, whitish yellow to yellowish white fluorescence, yielding no cut to a whitish - milky, very slow streaming cut; and no to slight odour.
    The Brent Formation sand was encountered at 3987 m. Two sand sequences, 53 m and 68 m thick separated with 20 m shale, were drilled through. Core No. 3 was cut from the upper part. The sandstone was grey to white, very fine to fine grained, well sorted with calcite and illite cement. Average porosity was 15.6%, with permeability up to 5.8 mD. The Statfjord Formation was penetrated from 4353 m. One core (core No. 4) was cut. The sandstone was light grey to medium grey, very fine to very coarse grained, poor sorted, kaolinitic and with calcite cement. Average porosity was 9.7%, permeability up to 9.6 mD. Thesandstone was water bearing. No fluid samples were taken on wire line. The well was permanently abandoned as a dry well on 30 March 1982.
    Testing
    No drill stem test was performed

  • Cuttings at the Norwegian Offshore Directorate
    Cuttings at the Norwegian Offshore Directorate
    Cuttings available for sampling?
    NO
    Cuttings at the Norwegian Offshore Directorate
    Cutting sample, top depth [m]
    Cutting samples, bottom depth [m]
    520.00
    4460.00

  • 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
    3567.0
    3576.2
    [m ]
    2
    3576.2
    3584.7
    [m ]
    3
    3990.9
    4006.8
    [m ]
    4
    4358.0
    4365.5
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    41.1
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 3568-3573m
    Core photo at depth: 3574-3576m
    Core photo at depth: 3577-3582m
    Core photo at depth: 3583-3584m
    Core photo at depth: 3991-3996m
    3568-3573m
    3574-3576m
    3577-3582m
    3583-3584m
    3991-3996m
    Core photo at depth: 4003-4006m
    Core photo at depth: 4359-4364m
    Core photo at depth: 4365-4366m
    Core photo at depth: 3996-4002m
    Core photo at depth:  
    4003-4006m
    4359-4364m
    4365-4366m
    3996-4002m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    540.0
    [m]
    DC
    RRI
    830.0
    [m]
    DC
    RRI
    1110.0
    [m]
    DC
    RRI
    1420.0
    [m]
    DC
    RRI
    1700.0
    [m]
    DC
    RRI
    2000.0
    [m]
    DC
    RRI
    2300.0
    [m]
    DC
    RRI
    2600.0
    [m]
    DC
    RRI
    2900.0
    [m]
    DC
    RRI
    3120.0
    [m]
    DC
    RRI
    3300.0
    [m]
    DC
    RRI
    3450.0
    [m]
    DC
    RRI
    3479.0
    [m]
    SWC
    RRI
    3491.0
    [m]
    DC
    RRI
    3507.0
    [m]
    SWC
    RRI
    3528.0
    [m]
    SWC
    RRI
    3530.0
    [m]
    DC
    RRI
    3535.0
    [m]
    SWC
    RRI
    3541.0
    [m]
    SWC
    RRI
    3576.4
    [m]
    SWC
    RRI
    3608.0
    [m]
    SWC
    RRI
    3624.0
    [m]
    SWC
    RRI
    3665.0
    [m]
    SWC
    RRI
    3700.0
    [m]
    SWC
    RRI
    3761.0
    [m]
    DC
    RRI
    3768.0
    [m]
    SWC
    RRI
    3794.0
    [m]
    DC
    RRI
    3800.0
    [m]
    DC
    RRI
    3807.0
    [m]
    SWC
    RRI
    3828.0
    [m]
    SWC
    RRI
    3830.0
    [m]
    DC
    RRI
    3852.0
    [m]
    SWC
    RRI
    3854.0
    [m]
    DC
    RRI
    3890.0
    [m]
    DC
    RRI
    3920.0
    [m]
    DC
    RRI
    3924.0
    [m]
    SWC
    RRI
    3950.0
    [m]
    DC
    RRI
    3962.0
    [m]
    DC
    RRI
    3974.8
    [m]
    C
    RRI
    4004.1
    [m]
    C
    RRI
    4022.3
    [m]
    C
    RRI
    4052.6
    [m]
    C
    RRI
    4055.0
    [m]
    SWC
    RRI
    4073.8
    [m]
    C
    RRI
    4094.1
    [m]
    C
    RRI
    4103.0
    [m]
    DC
    RRI
    4223.0
    [m]
    DC
    RRI
    4345.0
    [m]
    SWC
    RRI
    4358.0
    [m]
    SWC
    RRI
    4408.0
    [m]
    SWC
    RRI
    4433.0
    [m]
    DC
    RRI

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.77

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    6.18
    pdf
    0.84
    pdf
    2.45
    pdf
    0.37
    pdf
    2.45
    pdf
    0.37
    pdf
    0.12
    pdf
    0.43

  • 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
    18.16

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL VDL GR
    1770
    2365
    CST
    3407
    4455
    DLL MSFL GR
    3960
    4460
    FDC CNL GR
    1006
    2209
    FDC CNL GR
    2193
    3412
    FDC CNL GR
    3684
    4460
    FDC CNT GR
    3390
    3684
    GR
    366
    516
    HDT
    3390
    4413
    ISF BHC GR
    516
    1017
    ISF BHC GR
    1006
    2208
    ISF BHC GR
    2193
    3407
    ISF BHC GR
    3390
    3682
    ISF BHC NGT GR
    3390
    4459
    RFT
    3390
    4413
    VSP
    725
    4459

  • 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
    516.0
    36
    516.0
    0.00
    LOT
    SURF.COND.
    20
    1006.0
    26
    1019.0
    1.52
    LOT
    INTERM.
    13 3/8
    2197.0
    17 1/2
    2209.0
    1.76
    LOT
    INTERM.
    9 5/8
    3388.0
    12 1/4
    3406.0
    1.90
    LOT
    OPEN HOLE
    4460.0
    8 1/2
    4460.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    555
    1.10
    water based
    990
    1.10
    water based
    1420
    1.18
    water based
    2080
    1.28
    water based
    2340
    1.32
    water based
    2800
    1.34
    water based
    3300
    1.26
    water based
    3570
    1.48
    water based
    3880
    1.51
    water based
    4300
    1.56
    water based

  • Thin sections at the Norwegian Offshore Directorate
    Thin sections at the Norwegian Offshore Directorate
    Depth
    Unit
    4358.80
    [m ]
    4359.60
    [m ]
    4365.30
    [m ]
    4364.06
    [m ]
    4358.07
    [m ]
    3990.00
    [m ]
    4365.00
    [m ]
    3998.10
    [m ]
    4359.00
    [m ]
    4006.50
    [m ]

  • 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
    0.23