Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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33/6-1

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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.
    33/6-1
    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.
    33/6-1
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    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 Agip 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.
    212-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.
    89
    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,
    09.04.1979
    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.
    06.07.1979
    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.
    06.07.1981
    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.
    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.
    306.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3900.0
    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).
    3898.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    3.5
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    103
    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° 32' 14.83'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    1° 51' 57.55'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6823341.21
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    439704.03
    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.
    406

  • Wellbore history
    General
    Well 33/6-1 is located in the Marulk Basin northwest of the Snorre Field in the southeastern sector of block 33/6. The location was selected on the crestal area of the most attractive feature in the licence: a fault bounded, tilted block. The closure was considered dependent upon the sealing properties of the NE-SW fault to the south of the prospect. The primary objective of the well was to test the Middle-Early Jurassic Brent-Statfjord reservoirs. Planned TD was in the Late Triassic Hegre Group
    Operations and results
    Exploration well 33/6-1 was spudded on April 9, 1979 in 306 m water depth, the deepest drilling location to that date. Semi-submersible installation Fernstar was used to drill the well. Due to soft bottom conditions and problems with stabilizing the temporary guide base on the sea floor the well was re-spudded twice, the last and successful attempt on April 15. The well reached TD at 3900 m in the Early Jurassic Statfjord Formation. The well was drilled with seawater and pre-hydrated bentonite down 434 m, with seawater/HPD polymer/bentonite from 434 m to 695 m, with KCl/Dextrid/seawater from 695 m to 1690 m, and with lignosulphonate/fresh water from 1690 m to TD.
    The most significant horizons, the top of the Paleocene Seismic Marker and top Cretaceous, came in 13 meters lower and 37,5 meters higher than expected, respectively. The pre-Cretaceous section deviated significantly from prognosis. This was caused by a very crude depth conversion model due to lack of well control in the area and a much thinner Brent thickness than prognosed. All pre-Cretaceous targets were found however. The Late Kimmerian unconformity was encountered 133.5 m high to prognosis. The Late Jurassic shale was 65.5 m thick, 35 meters thicker than prognosed and consisted of 30 m of Draupne Formation plus 35.5 m of Heather Formation.
    The primary target Brent Group was penetrated at 3603 m, 97 meters higher than prognosed, and only 44 m thick versus the expected 155 m. The Brent reservoir was water wet. This was evident on the logs and was confirmed by no shows on the cuttings, mud, or on core. The Dunlin Group came in at 3647.5 m, 297 m higher than prognosed, and was 144.5 m thick compared to the expected 265 m
    The secondary target Statfjord Formation was encountered at 3792 m, 328 m higher than prognosed and was 70 m thick, 10 meters more than predicted. The Statfjord reservoir was water wet. Again this was evident on the logs and was confirmed by no shows on the cuttings, mud, or on core.á
    Two cores were cut. The first core was cut from 3607 m to 3616 m in the Brent Group and the second from 3802 m to 3807 m in the Statfjord Formation. No fluid samples were taken in this well.
    The well was permanently abandoned on 6 July 1979 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]
    450.00
    3900.00

  • 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
    3607.0
    3615.5
    [m ]
    2
    3802.0
    3806.6
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    13.1
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1300.0
    [m]
    DC
    GEOCH
    1330.0
    [m]
    DC
    GEOCH
    1360.0
    [m]
    DC
    GEOCH
    1390.0
    [m]
    DC
    GEOCH
    1400.0
    [m]
    DC
    GEOCH
    1420.0
    [m]
    DC
    GEOCH
    1420.0
    [m]
    DC
    RRI
    1440.0
    [m]
    DC
    RRI
    1450.0
    [m]
    DC
    GEOCH
    1460.0
    [m]
    DC
    RRI
    1480.0
    [m]
    DC
    RRI
    1480.0
    [m]
    DC
    GEOCH
    1500.0
    [m]
    DC
    RRI
    1510.0
    [m]
    DC
    GEOCH
    1520.0
    [m]
    DC
    GEOCH
    1540.0
    [m]
    DC
    GEOCH
    1560.0
    [m]
    DC
    GEOCH
    1570.0
    [m]
    DC
    GEOCH
    1580.0
    [m]
    DC
    RRI
    1600.0
    [m]
    DC
    RRI
    1600.0
    [m]
    DC
    GEOCH
    1620.0
    [m]
    DC
    RRI
    1630.0
    [m]
    DC
    GEOCH
    1640.0
    [m]
    DC
    RRI
    1660.0
    [m]
    DC
    RRI
    1660.0
    [m]
    DC
    GEOCH
    1680.0
    [m]
    DC
    RRI
    1690.0
    [m]
    DC
    GEOCH
    1700.0
    [m]
    DC
    RRI
    1720.0
    [m]
    DC
    RRI
    1720.0
    [m]
    DC
    GEOCH
    1740.0
    [m]
    DC
    RRI
    1750.0
    [m]
    DC
    GEOCH
    1760.0
    [m]
    DC
    RRI
    1780.0
    [m]
    DC
    GEOCH
    1780.0
    [m]
    DC
    RRI
    1800.0
    [m]
    DC
    RRI
    1810.0
    [m]
    DC
    GEOCH
    1820.0
    [m]
    DC
    RRI
    1840.0
    [m]
    DC
    RRI
    1840.0
    [m]
    DC
    GEOCH
    1860.0
    [m]
    DC
    RRI
    1870.0
    [m]
    DC
    GEOCH
    1880.0
    [m]
    DC
    RRI
    1900.0
    [m]
    DC
    RRI
    1900.0
    [m]
    DC
    GEOCH
    1930.0
    [m]
    DC
    GEOCH
    1960.0
    [m]
    DC
    GEOCH
    1995.0
    [m]
    DC
    GEOCH
    2110.0
    [m]
    SWC
    AGIP
    2130.0
    [m]
    SWC
    AGIP
    2221.0
    [m]
    SWC
    AGIP
    2235.0
    [m]
    SWC
    AGIP
    2630.0
    [m]
    SWC
    AGIP
    2730.0
    [m]
    SWC
    AGIP
    2870.0
    [m]
    SWC
    AGIP
    2950.0
    [m]
    SWC
    AGIP
    3200.0
    [m]
    DC
    OD
    3215.0
    [m]
    SWC
    AGIP
    3257.0
    [m]
    SWC
    AGIP
    3260.0
    [m]
    DC
    OD
    3280.0
    [m]
    DC
    OD
    3300.0
    [m]
    SWC
    AGIP
    3305.0
    [m]
    DC
    OD
    3320.0
    [m]
    DC
    OD
    3330.0
    [m]
    DC
    OD
    3360.0
    [m]
    DC
    OD
    3368.0
    [m]
    SWC
    AGIP
    3400.0
    [m]
    DC
    OD
    3403.0
    [m]
    SWC
    AGIP
    3437.0
    [m]
    SWC
    AGIP
    3455.0
    [m]
    DC
    OD
    3468.0
    [m]
    SWC
    AGIP
    3525.0
    [m]
    SWC
    AGIP
    3542.0
    [m]
    SWC
    AGIP
    3592.0
    [m]
    SWC
    AGIP
    3601.0
    [m]
    SWC
    AGIP
    3604.0
    [m]
    SWC
    AGIP
    3605.0
    [m]
    C
    AGIP
    3610.0
    [m]
    C
    AGIP
    3645.0
    [m]
    SWC
    AGIP
    3674.0
    [m]
    SWC
    AGIP
    3712.0
    [m]
    SWC
    AGIP
    3730.0
    [m]
    SWC
    AGIP
    3750.0
    [m]
    SWC
    AGIP
    3772.0
    [m]
    SWC
    AGIP
    3777.0
    [m]
    SWC
    AGIP
    3787.0
    [m]
    SWC
    AGIP
    3789.0
    [m]
    SWC
    AGIP
    3801.0
    [m]
    C
    AGIP
    3814.0
    [m]
    SWC
    AGIP
    3835.0
    [m]
    SWC
    AGIP
    3843.0
    [m]
    SWC
    AGIP
    3871.0
    [m]
    SWC
    AGIP
    3883.0
    [m]
    SWC
    AGIP
    3895.0
    [m]
    SWC
    AGIP

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.52

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    2.13
    pdf
    0.21
    pdf
    0.67

  • 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
    26.33

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL
    315
    692
    CBL
    1900
    3532
    FDC CNL GR
    1960
    3901
    HDT
    1959
    3898
    HRT
    300
    1627
    ISF BHC SP GR
    434
    3901
    VSP
    623
    3900

  • 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
    434.0
    36
    440.0
    0.00
    LOT
    SURF.COND.
    20
    695.0
    26
    715.0
    1.26
    LOT
    INTERM.
    13 3/8
    1960.0
    17 1/2
    1987.0
    1.65
    LOT
    INTERM.
    9 5/8
    3527.0
    12 1/4
    3550.0
    1.91
    LOT
    OPEN HOLE
    3900.0
    8 1/2
    3900.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    644
    1.11
    water based
    850
    1.10
    water based
    1139
    1.23
    water based
    1987
    1.27
    water based
    2338
    1.38
    water based
    3333
    1.42
    water based
    3424
    1.45
    water based
    3550
    1.51
    water based
    3846
    1.53
    water based