Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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25.11.2024 - 01:30
Time of last synchronization with Norwegian Offshore Directorate's internal systems

30/11-5

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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.
    30/11-5
    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
    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.
    30/11-5
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    SH 9004-839 & CROSSLINE 719
    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 Norwegian Offshore Directorate.
    868-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.
    36
    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,
    05.12.1996
    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.
    09.01.1997
    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.
    09.01.1999
    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.
    15.02.2006
    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
    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.
    YES
    1st level with HC, age
    Age of lithostratigraphic unit, 1st level, where hydrocarbons were encountered. Examples of legal values: CRETACEOUS, EARLY CRETACEOUS, LATE JURASSIC, EOCENE. See also Norwegian Offshore Directorate bulletins.
    MIDDLE JURASSIC
    1st level with HC, formation
    Name of lithostartigraphic unit, 1st level, where hydrocarbons were encountered. Shown only for released wells. Examples of legal values: BASEMENT, COOK FM, EKOFISK FM, HEIMDAL FM, SANDNES FM, SOGNEFJORD FM, TARBERT FM, BRENT GP. See also Norwegian Offshore Directorate bulletins.
    BRENT GP
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    23.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    105.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3726.0
    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).
    3725.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    8.3
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    114
    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.
    DRAKE FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    60° 8' 50.39'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 33' 59.57'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6668054.43
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    475929.50
    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.
    2986

  • Wellbore history
    General
    Well 30/11-5 is located in the Viking Graben in the North Sea, between the Oseberg Field area and the Frigg Field area. The objective of the well was to test the presence of hydrocarbons in Middle Jurassic Brent Group sandstones in the "Steinbit" prospect, a fault-dependent structure in Block 30/11.
    Operations and results
    Wildcat well 30/11-5 was spudded with the semi-submersible installation Maersk Jutlander on 5 December 1996 and drilled to TD at 3726 m in the Early Jurassic Drake Formation. A boulder bed in the top hole from 160 m to 180 m caused some difficulties with entering the 30" surface conductor casing. The GST (geosteering motor with resistivity at the bit) failed in the 8 1/2" section, and was substituted with a MWD/CDR configured in rotary mode to bring the resistivity sensor as close to the bit as possible. The well was drilled with seawater and bentonite hi-vis pills down to 1430 m, and with sodium silicate (Barasilc) mud from 1430 m to 3098 m. From 3098 m to TD the Barasilc mud was gradually replaced with KCl/polymer mud. The Barasilc mud consists of soluble silicates and KCl/polymer based fluid.
    The well found the Middle Jurassic Tarbert and Ness Formations within prognosis ranges, with good porosities. A total of 19.2 m net oil pay distributed in several thin intervals was encountered in the well, overlying water-bearing sandstones. Two OWC's were placed at 3366 m and at 3432 m. Evaluation of the RFT data from well 30/11-5 shows different reservoir pressures between the wells 30/11-5 and the wells 30/11-3 and -4 to the south and 30/9-16 to the north. The pore pressures are also different between the various Tarbert reservoirs within 30/11-5, although the data remain in a hydrostatic pressure regime.
    Oil shows on cuttings were described as follows: 3249 - 3310 m, on siltstone, limestone, and coal: weak blue white fluorescence with a slow white cut. Some mineral fluorescence in the limestone streaks; 3417 - 3438 m on clean, fine to medium sandstone: traces of blue white direct fluorescence, no cut and no residual fluorescence.
    The criterion for coring was based on real-time resistivity reading from the GST, and when this tool did not work and other real-time criteria (poor shows, low gas readings) were not met, the planned 18 m core in Tarbert and Ness was omitted. The RFT tool acquired 13 good pressure points to evaluate pressure gradients. No fluid samples were taken.
    The well was permanently abandoned on 9 January 1997 as a minor oil discovery.
    Testing
    No drill stem test was performed in the well.

  • 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]
    1440.00
    3726.00

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1710.0
    [m]
    DC
    RRI
    1740.0
    [m]
    DC
    RRI
    1760.0
    [m]
    DC
    RRI
    1780.0
    [m]
    DC
    RRI
    1800.0
    [m]
    DC
    RRI
    1820.0
    [m]
    DC
    RRI
    1840.0
    [m]
    DC
    RRI
    1870.0
    [m]
    DC
    RRI
    1890.0
    [m]
    DC
    RRI
    1910.0
    [m]
    DC
    RRI
    1930.0
    [m]
    DC
    RRI
    1950.0
    [m]
    DC
    RRI
    1970.0
    [m]
    DC
    RRI
    1990.0
    [m]
    DC
    RRI
    2010.0
    [m]
    DC
    RRI
    2030.0
    [m]
    DC
    RRI
    2050.0
    [m]
    DC
    RRI
    2070.0
    [m]
    DC
    RRI
    2090.0
    [m]
    DC
    RRI
    2110.0
    [m]
    DC
    RRI
    2130.0
    [m]
    DC
    RRI
    2150.0
    [m]
    DC
    RRI
    2170.0
    [m]
    DC
    RRI
    2190.0
    [m]
    DC
    RRI
    2210.0
    [m]
    DC
    RRI
    2230.0
    [m]
    DC
    RRI
    2250.0
    [m]
    DC
    RRI
    2270.0
    [m]
    DC
    RRI
    2290.0
    [m]
    DC
    RRI
    2310.0
    [m]
    DC
    RRI
    2330.0
    [m]
    DC
    RRI
    2350.0
    [m]
    DC
    RRI
    2370.0
    [m]
    DC
    RRI
    2390.0
    [m]
    DC
    RRI
    2410.0
    [m]
    DC
    RRI
    2430.0
    [m]
    DC
    RRI
    2450.0
    [m]
    DC
    RRI
    2470.0
    [m]
    DC
    RRI
    2490.0
    [m]
    DC
    RRI
    2510.0
    [m]
    DC
    RRI
    2530.0
    [m]
    DC
    RRI
    2550.0
    [m]
    DC
    RRI
    2570.0
    [m]
    DC
    RRI
    2590.0
    [m]
    DC
    RRI
    2610.0
    [m]
    DC
    RRI
    2630.0
    [m]
    DC
    RRI
    2650.0
    [m]
    DC
    RRI
    2670.0
    [m]
    DC
    RRI
    2930.0
    [m]
    DC
    RRI
    2950.0
    [m]
    DC
    RRI
    2970.0
    [m]
    DC
    RRI
    2990.0
    [m]
    DC
    RRI
    3010.0
    [m]
    DC
    RRI
    3030.0
    [m]
    DC
    RRI
    3050.0
    [m]
    DC
    RRI
    3070.0
    [m]
    DC
    RRI
    3090.0
    [m]
    DC
    RRI
    3111.0
    [m]
    DC
    RRI
    3132.0
    [m]
    DC
    RRI
    3144.0
    [m]
    DC
    RRI
    3165.0
    [m]
    DC
    RRI
    3186.0
    [m]
    DC
    RRI
    3207.0
    [m]
    DC
    RRI
    3228.0
    [m]
    DC
    RRI
    3249.0
    [m]
    DC
    RRI
    3270.0
    [m]
    DC
    RRI
    3291.0
    [m]
    DC
    RRI
    3312.0
    [m]
    DC
    RRI
    3330.0
    [m]
    DC
    RRI
    3372.0
    [m]
    DC
    RRI
    3390.0
    [m]
    DC
    RRI
    3411.0
    [m]
    DC
    RRI
    3432.0
    [m]
    DC
    RRI
    3453.0
    [m]
    DC
    RRI
    3471.0
    [m]
    DC
    RRI
    3492.0
    [m]
    DC
    RRI
    3513.0
    [m]
    DC
    RRI
    3534.0
    [m]
    DC
    RRI
    3555.0
    [m]
    DC
    RRI
    3576.0
    [m]
    DC
    RRI
    3597.0
    [m]
    DC
    RRI
    3618.0
    [m]
    DC
    RRI
    3639.0
    [m]
    DC
    RRI
    3660.0
    [m]
    DC
    RRI
    3681.0
    [m]
    DC
    RRI
    3702.0
    [m]
    DC
    RRI
    3723.0
    [m]
    DC
    RRI

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.27

  • 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
    7.91
    pdf
    39.89
    pdf
    5.11

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    AS LDL CNL GR AMS
    1700
    2250
    LDL AS CNL
    0
    0
    MWD LWD - CDR
    2708
    3726
    MWD LWD - GR
    405
    920
    MWD LWD - GR RES DIR
    1750
    2708
    NGS DLL MSFL CAL
    3088
    3726
    RFT RPQS GR AMS
    3088
    3726
    VSP GR
    2158
    3720

  • 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
    225.0
    36
    227.0
    0.00
    LOT
    SURF.COND.
    14
    1419.0
    17 1/2
    1420.0
    0.00
    LOT
    INTERM.
    9 5/8
    2085.0
    12 1/4
    2090.0
    0.00
    LOT
    OPEN HOLE
    3726.0
    8 1/2
    3726.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    190
    1.05
    SEAWATER
    214
    1.05
    SEAWATER
    1430
    1.05
    SEAWATER
    1430
    1.05
    SEAWATER
    2274
    1.41
    54.0
    BARASILC
    2597
    1.39
    56.0
    BARASILC
    3167
    1.32
    60.0
    BARASILC
    3726
    1.35
    87.0
    BARASILC

  • 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