Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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06.11.2024 - 01:25
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30/6-6

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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.
    30/6-6
    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).
    APPRAISAL
    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
    Field
    Name of the field the wellbore is related to.
    Discovery
    Name of the discovery the wellbore is related to.
    Well name
    Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    30/6-6
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    8006 - 203 SP 280
    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.
    Den norske stats oljeselskap a.s
    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.
    311-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.
    75
    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,
    09.01.1982
    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.
    24.03.1982
    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.
    24.03.1984
    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.
    29.03.2014
    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.
    APPRAISAL
    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.
    114.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3225.0
    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).
    3224.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    2.5
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    125
    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.
    COOK FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    60° 36' 43.43'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 49' 54.11'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6719748.76
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    490785.95
    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.
    39

  • Wellbore history
    General
    Well 30/6-6 was drilled on the 30/6 Alpha structure (Oseberg fault block) in the North Sea, as the fifth well drilled on this structure. The well was drilled down-dip of 30/6-3 and 30/6-4. The primary objective of this well was to define the oil-water contact for the structure. This would be achieved by penetrating the OWC or by extrapolation of fluid gradients from RFT and DST pressure measurements.
    Operations and results
    Appraisal well 30/6-6 was spudded with the semi-submersible installation Deepsea Saga on 9 January 1982 and drilled to TD at 3225 m in the Early Jurassic Cook Formation. Drilling operations proceeded without specific problems down to ca 1300 m. At this depth problems related to excessive torque and drag on short trips occurred. The mud weight was then reduced from 1.4 to 1.29 after which drilling again proceeded without problems. The well was drilled with spud mud down to 200 m, with Gel/seawater/spud mud from 200 m to 1793 m, and with gel/lignosulphonate mud from 1793 m to TD.
    Top Viking Group was penetrated at 2587 m and consisted of 113 m Draupne Formation shales on top of 120 m Heather Formation. The Brent Group was encountered at 2820 m. It was water bearing. Combined RFT-pressures from 30/6-6 and 30/6-4 gave an oil/water contact at 2720 +/- 20 m, which was later confirmed by the build-up pressures from the DST and the calculated water density under reservoir conditions. No indications of H2S were seen in this well. No shows are reported from the well.
    Three cores were taken in the Ness and Etive formations from 2921 m - 2964 m. RFT water samples were attempted at 2879 m, 2955 m and 2956 m, but were only moderately successful due to poor recovery and contamination with cushion water.
    The well was permanently abandoned on 24 March 1982 as a dry well.
    Testing
    One DST was perforated over 2946 to 2962 m in the water zone in the Etive Formation. The well was production tested and tests on reservoir parameters were carried out, including use of tritium tracers. The well produced 380 m3 water /day through a 64/64" choke. The maximum flowing temperature recorded during the test was 116.5 deg C. Water samples were taken. The production test was followed by an injection test through the same perforations.

  • 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]
    200.00
    3224.00

  • 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
    2921.0
    2933.0
    [m ]
    2
    2936.5
    2954.0
    [m ]
    3
    2963.6
    2969.0
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    34.9
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 2926-2931m
    Core photo at depth: 2931-2933m
    Core photo at depth: 2935-2941m
    Core photo at depth: 2941-2946m
    Core photo at depth: 2946-2951m
    2926-2931m
    2931-2933m
    2935-2941m
    2941-2946m
    2946-2951m
    Core photo at depth: 2951-2954m
    Core photo at depth: 2963-2964m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    2951-2954m
    2963-2964m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1360.0
    [m]
    DC
    GEOCH
    1390.0
    [m]
    DC
    GEOCH
    1410.0
    [m]
    DC
    GEOCH
    1470.0
    [m]
    DC
    GEOCH
    1500.0
    [m]
    DC
    GEOCH
    1530.0
    [m]
    DC
    GEOCH
    1560.0
    [m]
    DC
    GEOCH
    1590.0
    [m]
    DC
    GEOCH
    1620.0
    [m]
    DC
    GEOCH
    1650.0
    [m]
    DC
    GEOCH
    1680.0
    [m]
    DC
    GEOCH
    1710.0
    [m]
    DC
    GEOCH
    1740.0
    [m]
    DC
    GEOCH
    1770.0
    [m]
    DC
    GEOCH
    1800.0
    [m]
    DC
    GEOCH
    1830.0
    [m]
    DC
    GEOCH
    1860.0
    [m]
    DC
    GEOCH
    1890.0
    [m]
    DC
    GEOCH
    1920.0
    [m]
    DC
    GEOCH
    1950.0
    [m]
    DC
    GEOCH
    1980.0
    [m]
    DC
    GEOCH
    2009.0
    [m]
    DC
    GEOCH
    2015.0
    [m]
    DC
    GEOCH
    2036.0
    [m]
    DC
    GEOCH
    2063.0
    [m]
    DC
    GEOCH
    2090.0
    [m]
    DC
    GEOCH
    2135.0
    [m]
    DC
    GEOCH
    2162.0
    [m]
    DC
    GEOCH
    2189.0
    [m]
    DC
    GEOCH
    2216.0
    [m]
    DC
    GEOCH
    2243.0
    [m]
    DC
    GEOCH
    2270.0
    [m]
    DC
    GEOCH
    2294.0
    [m]
    DC
    GEOCH
    2321.0
    [m]
    DC
    GEOCH
    2339.0
    [m]
    DC
    GEOCH
    2348.0
    [m]
    DC
    GEOCH
    2351.0
    [m]
    DC
    GEOCH
    2610.0
    [m]
    SWC
    RRI
    2626.0
    [m]
    SWC
    RRI
    2630.0
    [m]
    SWC
    RRI
    2654.0
    [m]
    SWC
    RRI
    2659.0
    [m]
    SWC
    RRI
    2689.0
    [m]
    SWC
    RRI
    2701.0
    [m]
    SWC
    RRI
    2722.0
    [m]
    SWC
    RRI
    2740.0
    [m]
    SWC
    RRI
    2760.0
    [m]
    SWC
    RRI
    2780.0
    [m]
    SWC
    RRI
    2792.0
    [m]
    SWC
    RRI
    2807.0
    [m]
    SWC
    RRI
    2819.0
    [m]
    SWC
    RRI
    2824.0
    [m]
    SWC
    RRI
    2831.0
    [m]
    SWC
    RRI
    2838.0
    [m]
    SWC
    RRI
    2861.0
    [m]
    SWC
    RRI
    2898.0
    [m]
    SWC
    RRI
    2928.5
    [m]
    SWC
    RRI
    2967.0
    [m]
    SWC
    RRI
    3010.0
    [m]
    SWC
    RRI
    3035.0
    [m]
    SWC
    RRI
    3151.0
    [m]
    SWC
    RRI

  • Lithostratigraphy

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    20.54
    pdf
    1.31
    pdf
    0.25
    pdf
    44.44
    pdf
    21.44

  • 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
    20.54

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    2946
    2962
    25.4
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    Drill stem tests (DST)
    Test number
    Oil
    [Sm3/day]
    Gas
    [Sm3/day]
    Oil density
    [g/cm3]
    Gas grav. rel.air
    GOR
    [m3/m3]
    1.0

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL CCL VDL GR
    450
    3046
    CDM AP
    2251
    3224
    FDC CNL GR CAL
    605
    3223
    HDT
    2552
    3224
    ISF SON MSFL GR
    131
    3223
    RFT HP
    2823
    3191
    VELOCITY
    131
    3223

  • 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
    199.5
    36
    200.0
    0.00
    LOT
    SURF.COND.
    20
    605.0
    26
    620.0
    1.48
    LOT
    INTERM.
    13 3/8
    1793.0
    17 1/2
    1815.0
    1.68
    LOT
    INTERM.
    9 5/8
    2251.0
    12 1/4
    2565.0
    1.74
    LOT
    LINER
    7
    3220.0
    8 1/2
    3220.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    200
    1.04
    40.0
    waterbased
    470
    1.08
    55.0
    waterbased
    955
    1.09
    53.0
    waterbased
    1310
    1.39
    86.0
    waterbased
    1655
    1.21
    56.0
    waterbased
    2190
    1.48
    54.0
    waterbased
    2570
    1.25
    49.0
    waterbased
    2815
    1.23
    55.0
    waterbased

  • 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
    0.22