Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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19.07.2024 - 01:27
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15/3-6

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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.
    15/3-6
    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.
    15/3-6
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    INLINE 1070 & CROSS-LINE 2336
    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.
    Amoco Norway Oil Company
    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.
    941-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.
    23
    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,
    14.12.1998
    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.
    05.01.1999
    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.
    05.01.2001
    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.
    18.12.2002
    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.
    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).
    2793.0
    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).
    2786.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    12.51
    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 CRETACEOUS
    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.
    JORSALFARE FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    58° 46' 23.41'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    1° 45' 14.9'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6515614.35
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    427951.24
    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.
    3250
  • Wellbore history

    General
    Well 15/3-6 was drilled to test the Paleocene Balder and Hermod sandstones of the Pinnsvin prospect, and had a licence requirement to penetrate Cretaceous age formations. The well was drilled within licence PL 187 (Amoco Norway, Statoil, Norsk Hydro). License PL 025 farmed into the well (Statoil, Elf, Total, Hydro) for 20% of well costs.
    Operations and results
    Wildcat well 15/3-6 was spudded 15. December 1998 with the semi-submersible installation Mærsk Jutlander, and drilled to TD at 2793 m in the Late Cretaceous Shetland Group. The well was drilled with seawater and hi-vis pills down to 1018 m and oil based mud (Versavert) from 944 m to TD.
    The Intra Balder and Hermod sandstones were encountered as prognosed but the well was found to be completely water wet all through. A wire line fluid sample was taken at 2160 m in the Intra Balder Formation Sandstone. Two cores were cut in the interval 2140 m to 2176 m in the Balder Formation and Intra Balder Formation sandstones, and one was cut from 2278 m to 2297.7 m in the Hermod Formation Sandstone.
    The well was plugged and abandoned as a dry hole on 5 January 1999.
    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]
    1020.00
    2793.00
  • 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
    2140.0
    2158.1
    [m ]
    2
    2158.1
    2175.7
    [m ]
    3
    2278.0
    2297.7
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    55.4
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES
  • Core photos

    Core photos
    Core photo at depth: 2140-2145m
    Core photo at depth: 2145-2150m
    Core photo at depth: 2150-2155m
    Core photo at depth: 2155-2159m
    Core photo at depth: 2159-2164m
    2140-2145m
    2145-2150m
    2150-2155m
    2155-2159m
    2159-2164m
    Core photo at depth: 2164-2169m
    Core photo at depth: 2169-2174m
    Core photo at depth: 2174-2281m
    Core photo at depth: 2281-2286m
    Core photo at depth: 2286-2291m
    2164-2169m
    2169-2174m
    2174-2281m
    2281-2286m
    2286-2291m
    Core photo at depth: 2291-2296m
    Core photo at depth: 2296-2298m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    2291-2296m
    2296-2298m
  • Palynological slides at the Norwegian Offshore Directorate

    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1020.0
    [m]
    DC
    RRI
    1050.0
    [m]
    DC
    RRI
    1080.0
    [m]
    DC
    RRI
    1110.0
    [m]
    DC
    RRI
    1140.0
    [m]
    DC
    RRI
    1170.0
    [m]
    DC
    RRI
    1200.0
    [m]
    DC
    RRI
    1230.0
    [m]
    DC
    RRI
    1260.0
    [m]
    DC
    RRI
    1290.0
    [m]
    DC
    RRI
    1320.0
    [m]
    DC
    RRI
    1350.0
    [m]
    DC
    RRI
    1370.0
    [m]
    DC
    RRI
    1410.0
    [m]
    DC
    RRI
    1430.0
    [m]
    DC
    RRI
    1470.0
    [m]
    DC
    RRI
    1490.0
    [m]
    DC
    RRI
    1530.0
    [m]
    DC
    RRI
    1550.0
    [m]
    DC
    RRI
    1556.0
    [m]
    SWC
    RRI
    1590.0
    [m]
    DC
    RRI
    1610.0
    [m]
    DC
    RRI
    1650.0
    [m]
    DC
    RRI
    1670.0
    [m]
    DC
    RRI
    1710.0
    [m]
    DC
    RRI
    1730.0
    [m]
    DC
    RRI
    1770.0
    [m]
    DC
    RRI
    1810.0
    [m]
    DC
    RRI
    1830.0
    [m]
    DC
    RRI
    1850.0
    [m]
    DC
    RRI
    1860.0
    [m]
    SWC
    RRI
    1890.0
    [m]
    DC
    RRI
    1910.0
    [m]
    DC
    RRI
    1940.0
    [m]
    DC
    RRI
    1967.0
    [m]
    SWC
    RRI
    1970.0
    [m]
    DC
    RRI
    2010.0
    [m]
    DC
    RRI
    2035.0
    [m]
    SWC
    RRI
    2040.0
    [m]
    DC
    RRI
    2060.0
    [m]
    DC
    RRI
    2100.0
    [m]
    DC
    RRI
    2110.0
    [m]
    DC
    RRI
    2127.0
    [m]
    SWC
    RRI
    2130.0
    [m]
    DC
    RRI
    2140.0
    [m]
    C
    RRI
    2150.0
    [m]
    C
    RRI
    2170.0
    [m]
    C
    RRI
    2171.0
    [m]
    C
    RRI
    2176.0
    [m]
    C
    RRI
    2182.0
    [m]
    SWC
    RRI
    2191.0
    [m]
    DC
    RRI
    2206.0
    [m]
    DC
    RRI
    2212.0
    [m]
    SWC
    RRI
    2221.0
    [m]
    DC
    RRI
    2236.0
    [m]
    DC
    RRI
    2239.0
    [m]
    SWC
    RRI
    2251.0
    [m]
    DC
    RRI
    2254.0
    [m]
    SWC
    RRI
    2264.0
    [m]
    SWC
    RRI
    2266.0
    [m]
    DC
    RRI
    2267.0
    [m]
    SWC
    RRI
    2281.0
    [m]
    C
    RRI
    2287.0
    [m]
    C
    RRI
    2292.0
    [m]
    C
    RRI
    2297.0
    [m]
    C
    RRI
    2308.0
    [m]
    DC
    RRI
    2315.0
    [m]
    SWC
    RRI
    2326.0
    [m]
    DC
    RRI
    2336.0
    [m]
    SWC
    RRI
    2338.0
    [m]
    DC
    RRI
    2354.0
    [m]
    SWC
    RRI
    2356.0
    [m]
    DC
    RRI
    2368.0
    [m]
    DC
    RRI
    2383.0
    [m]
    DC
    RRI
    2391.0
    [m]
    SWC
    RRI
    2404.0
    [m]
    DC
    RRI
    2412.0
    [m]
    SWC
    RRI
    2419.0
    [m]
    DC
    RRI
    2428.0
    [m]
    DC
    RRI
    2434.0
    [m]
    SWC
    RRI
    2446.0
    [m]
    DC
    RRI
    2454.0
    [m]
    SWC
    RRI
    2458.0
    [m]
    DC
    RRI
    2476.0
    [m]
    DC
    RRI
    2496.0
    [m]
    DC
    RRI
    2503.0
    [m]
    DC
    RRI
    2521.0
    [m]
    DC
    RRI
    2523.0
    [m]
    SWC
    RRI
    2536.0
    [m]
    DC
    RRI
    2537.0
    [m]
    SWC
    RRI
    2548.0
    [m]
    DC
    RRI
    2549.0
    [m]
    SWC
    RRI
    2566.0
    [m]
    DC
    RRI
    2578.0
    [m]
    DC
    RRI
    2590.0
    [m]
    DC
    RRI
    2608.0
    [m]
    DC
    RRI
    2629.0
    [m]
    SWC
    RRI
    2632.0
    [m]
    DC
    RRI
    2641.0
    [m]
    DC
    RRI
    2644.0
    [m]
    SWC
    RRI
    2656.0
    [m]
    DC
    RRI
    2668.0
    [m]
    DC
    RRI
    2686.0
    [m]
    DC
    RRI
    2698.0
    [m]
    SWC
    RRI
    2704.0
    [m]
    DC
    RRI
    2716.0
    [m]
    DC
    RRI
    2728.0
    [m]
    DC
    RRI
    2746.0
    [m]
    DC
    RRI
    2753.0
    [m]
    SWC
    RRI
    2758.0
    [m]
    DC
    RRI
    2760.0
    [m]
    SWC
    RRI
    2764.0
    [m]
    DC
    RRI
    2767.0
    [m]
    SWC
    RRI
    2776.0
    [m]
    DC
    RRI
    2788.0
    [m]
    DC
    RRI
    2793.0
    [m]
    DC
    RRI
  • Lithostratigraphy

  • Composite logs

    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.41
  • Geochemical information

    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.13
  • 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
    3.19
    .pdf
    50.59
  • Logs

    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CST
    1560
    2767
    MDT
    1246
    2560
    MWD - CDR RES GR
    217
    2278
    MWD - CDR RES GR
    2304
    2793
    PEX DSI AIT GR
    260
    1002
  • 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
    212.0
    36
    216.0
    0.00
    LOT
    INTERM.
    13 3/8
    1015.0
    17 1/2
    1015.0
    0.00
    LOT
    OPEN HOLE
    1018.0
    12 1/4
    1018.0
    2.01
    LOT
    OPEN HOLE
    2793.0
    8 1/2
    2793.0
    0.00
    LOT
  • Drilling mud

    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    156
    1.08
    12.0
    SPUD MUD
    216
    1.10
    30.0
    SPUD MUD
    680
    1.10
    31.0
    SPUD MUD
    890
    1.10
    32.0
    SPUD MUD
    1019
    1.31
    18.0
    VERSAVERT
    2084
    1.31
    21.0
    VERSAVERT
    2158
    1.31
    21.0
    VERSAVERT
    2249
    1.31
    22.0
    VERSA VERT
    2772
    1.31
    26.0
    VERSA VERT
    2793
    1.31
    26.0
    VERSA VERT
  • 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