Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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33/12-6

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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.
    33/12-6
    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.
    33/12-6
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    LINE MNG 42 SP.365
    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.
    Mobil Exploration Norway INC
    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.
    150-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.
    111
    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,
    02.03.1976
    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.
    21.06.1976
    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.
    21.06.1978
    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.
    02.12.2014
    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.
    139.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4612.0
    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).
    4612.0
    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° 4' 36.41'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    1° 57' 17.76'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6771950.39
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    443612.01
    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.
    119

  • Wellbore history
    General
    Well 33/12-6 was drilled on Tampen Spur in the North Sea between the Gullfaks Sør Field area and the UK border. The objective was to test a large structural feature in the southeastern part of Block 33/12, located across a major regional fault bounding the eastern flank of the Brent and Statfjord Fields. The targets were sands in the Early and Middle Jurassic sandstones of the Statfjord and Brent Groups.
    Operations and results
    Wildcat well 33/12-6 was spudded with the semi-submersible installation Norskald on 2 March 1976 and drilled to TD at 4612 m in the Triassic Hegre Group.
    The Middle Jurassic Brent Group was encountered at 2973. Gross thickness was 312 meters. Only rare fluorescence with minor gas readings were noted in the sands. Higher gas readings encountered were associated with coal beds. Using cutoffs of 40 percent clay volume and 12.5 percent porosity, Schlumberger’s coriband analysis indicates 103 meters of net sand with an average porosity of 20 percent. The coriband analysis showed the sands to be water wet with only 6 m of net pay with water saturations less than 65 percent, scattered throughout the unit. The Early Jurassic Statfjord Group sands were topped at 3721 meters. Gross thickness was 309.5 meters. Using the same cutoff parameters as for the Brent formation, log analysis indicated 149 meters of net sand with an average porosity of 16 percent and showed the sands to be water wet. Only 3 m of scattered thin zones had water saturations less than 65 percent. No shows were seen in the samples. However, the core in the Statfjord sands had residual oil saturation over the 6.51 meters recovered indicating earlier oil migration through the section.
    The core was cut from 3736 m to 3744 m in the Statfjord Group. Three FIT fluid samples were acquired. One retrieved 10.2 l filtrate and formation water from 3070 m and two were seal failures (3726.5 m and 3727.5 m).
    The well was permanently abandoned on 21 June 1976 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]
    252.00
    4612.00

  • 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
    3736.0
    3742.5
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    6.5
    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
    1290.0
    [m]
    DC
    RRI
    1308.0
    [m]
    DC
    RRI
    1356.0
    [m]
    DC
    RRI
    1380.0
    [m]
    DC
    RRI
    1398.0
    [m]
    DC
    RRI
    1416.0
    [m]
    DC
    RRI
    1446.0
    [m]
    DC
    RRI
    1464.0
    [m]
    DC
    RRI
    1506.0
    [m]
    DC
    RRI
    1536.0
    [m]
    DC
    RRI
    1554.0
    [m]
    DC
    RRI
    1584.0
    [m]
    DC
    RRI
    1614.0
    [m]
    DC
    RRI
    1644.0
    [m]
    DC
    RRI
    2373.0
    [m]
    DC
    RRI
    2403.0
    [m]
    DC
    RRI
    2433.0
    [m]
    DC
    RRI
    2463.0
    [m]
    DC
    RRI
    2493.0
    [m]
    DC
    RRI
    2523.0
    [m]
    DC
    RRI
    2553.0
    [m]
    DC
    RRI
    2583.0
    [m]
    DC
    RRI
    2610.0
    [m]
    DC
    RRI
    2643.0
    [m]
    DC
    RRI
    2664.0
    [m]
    DC
    RRI

  • Lithostratigraphy

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.40
    pdf
    0.27
    pdf
    1.42

  • 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
    2.69
    pdf
    3.58

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CDM
    2624
    3806
    CDM AP
    2624
    3806
    DLL MSFL
    2940
    4102
    FDC CNL
    1817
    4616
    ISF SON
    239
    4615
    VELOCITY
    239
    4117

  • 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
    241.0
    36
    241.0
    0.00
    SURF.COND.
    20
    470.0
    26
    484.0
    0.00
    INTERM.
    13 3/8
    1824.0
    17 1/2
    1835.0
    0.00
    INTERM.
    9 5/8
    2625.0
    12 1/4
    2631.0
    0.00
    OPEN HOLE
    4614.0
    8 1/2
    4614.0
    0.00

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    484
    1.01
    40.0
    waterbased
    1764
    1.19
    49.0
    waterbased
    2062
    1.24
    47.0
    waterbased
    2795
    1.49
    45.0
    waterbased
    3914
    1.50
    45.0
    waterbased
    4612
    1.47
    54.0
    waterbased