Factpages Norwegian petroleum directorate
Factpages Norwegian petroleum directorate
NPD          Norsk
04.06.2023 - 01:36
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30/11-3

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  • General information

    General information
    Attribute Value
    Wellbore name
    Official name of wellbore based on NPD guidelines for designation of wells and wellbores.
    30/11-3
    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 NPD.
    INJECTING: It was injected to the wellbore at the time of the operators last monthly report to the NPD.
    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 NPD guidelines for designation of wells and wellbores.
    30/11-3
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    81205 SP 554
    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.
    A/S Norske Shell
    Drill permit
    The drilling permit number together with the version of the drilling permit as stated in the drilling permit granted by the NPD.
    354-L
    Drilling facility
    NPD's name of the facility which the wellbore was drilled from.
    Drilling days
    Number of days from wellbore entry to wellbore completion.
    118
    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,
    17.11.1982
    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.
    14.03.1983
    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.
    14.03.1985
    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.
    13.08.2015
    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.
    OIL/GAS SHOWS
    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.
    112.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4662.0
    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).
    4660.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    4.6
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    141
    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.
    STATFJORD GP
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    60° 2' 38.59'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 32' 15.47'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6656563.03
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    474243.25
    UTM zone
    Universal Transverse Mercator zone. Examples of legal values: 31, 32, 33, 34.
    31
    NPDID wellbore
    NPD's unique id for the wellbore.
    62
  • Wellbore history

    General
    Well 30/11-3 was drilled in the Fensal sub-basin in an area east of the Frigg and Odin Fields in the North Sea. The primary objective was to test Middle Jurassic sandstones of the Brent Group and Early Jurassic sandstones of the Statfjord Group in a westward tilted horst block.
    The well is type well for the Hardråde Formation and reference well for the Svarte, Tryggvason and Kyrre formations.
    Operations and results
    Wildcat well 30/11-3 was spudded with the semi-submersible installation Borgny Dolphin on 17 November 1982 and drilled to TD at 4662 m in the Early Jurassic Statfjord Group. When entering sandstones in the Statfjord Group at 4637 m the well kicked, probably due to overpressured gas. After efforts to stabilise the well the decision was made to abandon the well before a full evaluation of the Statfjord Group had been made. The well was drilled with spud mud down to 640 m, with KCl/polymer mud from 640 m to 3053 m, and with Drispac/lignosulphonate - gel/Resinex mud from 3053 m to TD.
    Well 30/11-3 encountered reservoir quality sands in the Tertiary (Frigg Formation and Heimdal Formation) and in the Jurassic (Brent Group and Statfjord Group). Oil saturations were seen in several thin sands in the Brent Group between 3434 m and 4025 m. Core and log evaluation indicated that these were probably due to residual oil only (saturations below a cut-off value of 50%). True oil shows were recorded intermittently only between 3434 m and 3600 m. Possible pay zones with reasonable porosity and permeability would be thin, with a net of only 13 m based on petrophysical evaluation. Log evaluation also indicated high gas saturations (up to more than 80%) in the Statfjord Group. However, due to the short penetration of this reservoir, the significance of this discovery could not be assessed and the hydrocarbon contact was not be established. The well penetrated an unexpected thickness of sealing Dunlin Group shales, which were considered positive for the Statfjord Group prospects.
    Two cores were cut in succession in the interval 3445 m to 3478 m with 100% recovery. RFT fluid samples were taken at 3454 m (water + trace oil) and 3667 m (water).
    The well was permanently abandoned on 14 March 1983 as a dry well with shows.
    Testing
    No drill stem test was performed.
  • Cuttings at the NPD

    Cuttings at the NPD
    Cuttings available for sampling?
    YES
    Cuttings at the NPD
    Cutting sample, top depth [m]
    Cutting samples, bottom depth [m]
    260.00
    4662.00
  • Cores at the NPD

    Cores at the NPD
    Core sample number
    Core sample - top depth
    Core sample - bottom depth
    Core sample depth - uom
    1
    3445.0
    3459.8
    [m ]
    2
    3460.0
    3478.5
    [m ]
    Cores at the NPD
    Total core sample length [m]
    33.3
    Cores at the NPD
    Cores available for sampling?
    YES
  • Palynological slides at the NPD

    Palynological slides at the NPD
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1610.0
    [m]
    DC
    GEOCH
    1640.0
    [m]
    DC
    GEOCH
    1670.0
    [m]
    DC
    GEOCH
    1700.0
    [m]
    DC
    GEOCH
    1730.0
    [m]
    DC
    GEOCH
    1760.0
    [m]
    DC
    GEOCH
    1790.0
    [m]
    DC
    GEOCH
    1820.0
    [m]
    DC
    GEOCH
    1850.0
    [m]
    DC
    GEOCH
    1880.0
    [m]
    DC
    GEOCH
    1909.0
    [m]
    DC
    GEOCH
    1936.0
    [m]
    DC
    GEOCH
    1963.0
    [m]
    DC
    GEOCH
    1990.0
    [m]
    DC
    GEOCH
    2017.0
    [m]
    DC
    GEOCH
    2044.0
    [m]
    DC
    GEOCH
    2071.0
    [m]
    DC
    GEOCH
    2098.0
    [m]
    DC
    GEOCH
    2125.0
    [m]
    DC
    GEOCH
    2152.0
    [m]
    DC
    GEOCH
    2179.0
    [m]
    DC
    GEOCH
    2206.0
    [m]
    DC
    GEOCH
    2233.0
    [m]
    DC
    GEOCH
    2260.0
    [m]
    DC
    GEOCH
    2287.0
    [m]
    DC
    GEOCH
    2314.0
    [m]
    DC
    GEOCH
    2344.0
    [m]
    DC
    GEOCH
    2371.0
    [m]
    DC
    GEOCH
    2398.0
    [m]
    DC
    GEOCH
    2425.0
    [m]
    DC
    GEOCH
    2452.0
    [m]
    DC
    GEOCH
    2479.0
    [m]
    DC
    GEOCH
    2506.0
    [m]
    DC
    GEOCH
    2533.0
    [m]
    DC
    GEOCH
    2560.0
    [m]
    DC
    GEOCH
    2587.0
    [m]
    DC
    GEOCH
    2605.0
    [m]
    DC
    GEOCH
    2623.0
    [m]
    DC
    GEOCH
    3446.9
    [m]
    C
    SPT
    3449.9
    [m]
    C
    SPT
    3452.5
    [m]
    C
    SPT
    3459.2
    [m]
    C
    SPT
    3799.0
    [m]
    DC
    OD
    3808.0
    [m]
    DC
    OD
  • Lithostratigraphy

  • Geochemical information

    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.78
    pdf
    0.58
  • 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
    2.34
    pdf
    7.73
  • Logs

    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL VDL
    137
    2003
    CBL VDL
    1440
    3041
    CST
    0
    0
    DLL MSFL GR
    3041
    3798
    DLL MSFL GR
    4600
    4659
    HDT
    3041
    4475
    ISF BHC GR MSFL
    4400
    4655
    ISF BHC GR SP
    115
    1994
    ISF BHC GR SP
    137
    639
    ISF BHC GR SP
    627
    1114
    ISF BHC GR SP
    1994
    3052
    ISF BHC GR SP
    3041
    3801
    ISF BHC GR SP
    3400
    4473
    LDL CNL GR CAL
    115
    1994
    LDL CNL GR CAL
    235
    639
    LDL CNL GR CAL
    627
    1114
    LDL CNL GR CAL
    1994
    3032
    LDL CNL NGS CAL
    3041
    3802
    RFT
    3464
    3754
    VELOCITY
    639
    3345
  • 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
    236.0
    36
    248.0
    0.00
    LOT
    SURF.COND.
    20
    627.5
    26
    640.0
    1.23
    LOT
    INTERM.
    13 3/8
    1994.0
    17 1/2
    2023.0
    1.66
    LOT
    INTERM.
    9 5/8
    3041.0
    12 1/4
    3053.0
    1.83
    LOT
    OPEN HOLE
    4000.0
    8 1/2
    4662.0
    0.00
    LOT
  • Drilling mud

    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    148
    1.06
    waterbased
    870
    1.16
    waterbased
    1450
    1.17
    waterbased
    2190
    1.21
    waterbased
    3050
    1.40
    waterbased
    3800
    1.31
    waterbased
    4000
    1.30
    waterbased
    4662
    1.60
    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
    0.23