Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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12.11.2024 - 01:25
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16/2-8

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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.
    16/2-8
    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
    Press release
    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.
    16/2-8
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    LN0902-inline 2120 & crossline 6672
    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.
    Statoil Petroleum AS
    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.
    1346-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.
    34
    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,
    17.07.2011
    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.
    19.08.2011
    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.
    19.08.2013
    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.
    19.08.2013
    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.
    NO
    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.
    LATE 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.
    INTRA DRAUPNE FM SS
    2nd level with HC, age
    Age of lithostratigraphic unit, 2nd level, where hydrocarbons were encountered. Examples of legal values: CRETACEOUS, EARLY CRETACEOUS, LATE JURASSIC, EOCENE.
    MIDDLE JURASSIC
    2nd level with HC, formation
    Name of lithostartigraphic unit, 2nd 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.
    HUGIN FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    23.5
    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).
    2140.0
    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).
    2140.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    1
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    81
    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.
    SKAGERRAK FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    58° 48' 57'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 32' 30.6'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6519785.69
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    473535.66
    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.
    6562

  • Wellbore history
    General
    Statoil well 16/2-8 (Aldous Major South) was drilled about 4.2 kilometres west of the Lundin oil discovery well 16/2-6 (Avaldsnes) on the Utsira High in the North Sea. The 16/2-6 Avaldsnes discovery was proven in September 2010 in Middle-Late Jurassic reservoir rocks. The main objective of well 16/2-8 was to investigate the hydrocarbon potential in Late Jurassic sandstones in the Draupne Formation and the Middle Jurassic Hugin/Sleipner Formations. The secondary and third objectives were to explore the hydrocarbon potential in the Triassic Skagerrak Formation and in Chalks of the Late Cretaceous Shetland Group, respectively.
    Operations and results
    Wildcat well 16/2-8 was spudded with the semi-submersible installation Transocean Leader on 17 July 2011 and drilled to TD at 2140 m in the Triassic Skagerrak Formation. Neither shallow gas nor shallow water flow was observed and the well was drilled without significant problems. The well was drilled with seawater and bentonite sweeps down to 213 m, with seawater and bentonite/PAC RE sweeps from 213 m to 945 m, with Performadril WBM spec 6a from 945 m to 1573 m, and with Performadril Low sulphate WBM from 1573 m to TD.
    The top of the main reservoir, in the Draupne Formation, was picked at 1877 m. The reservoir (Draupne and Hugin Formations) showed excellent reservoir properties and contained oil. An oil column of 67.5 m was present down to 1944.5 m (1921 m TVD MSL), close to the contact level seen in the 16/2-6 Avaldsnes well. Pressure data showed that the 16/2-8 Aldous Major South and the 16/2-6 Avaldsnes discoveries are in the same pressure regime and thus in communication. The secondary objective, Skagerrak Formation was water wet. The third objective, the Shetland Group chalk had moderate to poor oil shows in the very top, from 1573 to 1622 m, with a pronounced wet gas peak from 1573 to 1601 m.
    Six cores were cut in the well. Cores 1 to 4 were cut from 1880.5 m to 1953.21 m in the Rødby Formation, across Draupne and Hugin formations and into the Sleipner Formation. Cores no 5 and 6 were cut from 1995 m to 2048.8 m in the Statfjord and Skagerrak formations. MDT wire line fluid samples were taken at 1882.1 m (oil), 1931.2 m (oil), 1945.0 m (water), 1945.4 m (water), and at 1947.2 m (water).
    Well 16/2-8 proved communication between the Aldous Major South discovery in PL265 and the Avaldsnes discovery in PL501 made by Well 16/2-6 in august 2010. The two discoveries will be developed together under the name Johan Sverdrup Field. Well 16/2-8 was permanently abandoned on 19 August 2011 as an oil appraisal.
    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]
    950.00
    2140.00

  • 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
    1880.5
    1907.7
    [m ]
    2
    1907.7
    1935.3
    [m ]
    3
    1935.3
    1952.0
    [m ]
    4
    1952.0
    1953.2
    [m ]
    5
    1995.0
    2022.5
    [m ]
    6
    2022.5
    2048.8
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    126.5
    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
    950.0
    [m]
    DC
    970.0
    [m]
    DC
    990.0
    [m]
    DC
    1010.0
    [m]
    DC
    1030.0
    [m]
    DC
    1050.0
    [m]
    DC
    1070.0
    [m]
    DC
    1090.0
    [m]
    DC
    1110.0
    [m]
    DC
    1130.0
    [m]
    DC
    1150.0
    [m]
    DC
    1180.0
    [m]
    DC
    1200.0
    [m]
    DC
    1240.0
    [m]
    DC
    1260.0
    [m]
    DC
    1280.0
    [m]
    DC
    1300.0
    [m]
    DC
    1320.0
    [m]
    DC
    1340.0
    [m]
    DC
    1360.0
    [m]
    DC
    1380.0
    [m]
    DC
    1400.0
    [m]
    DC
    1420.0
    [m]
    DC
    1440.0
    [m]
    DC
    1460.0
    [m]
    DC
    1480.0
    [m]
    DC
    1500.0
    [m]
    DC
    1520.0
    [m]
    DC
    1530.0
    [m]
    DC
    1540.0
    [m]
    DC
    1550.0
    [m]
    DC
    1560.0
    [m]
    DC
    1570.0
    [m]
    DC
    1576.0
    [m]
    DC
    1582.0
    [m]
    DC
    1600.0
    [m]
    DC
    1744.0
    [m]
    DC
    1750.0
    [m]
    DC
    1756.0
    [m]
    DC
    1762.0
    [m]
    DC
    1768.0
    [m]
    DC
    1774.0
    [m]
    DC
    1780.0
    [m]
    DC
    1792.0
    [m]
    DC
    1801.0
    [m]
    DC
    1807.0
    [m]
    DC
    1813.0
    [m]
    DC
    1819.0
    [m]
    DC
    1825.0
    [m]
    DC
    1831.0
    [m]
    DC
    1837.0
    [m]
    DC
    1843.0
    [m]
    DC
    1849.0
    [m]
    DC
    1852.0
    [m]
    DC
    1855.0
    [m]
    DC
    1858.0
    [m]
    DC
    1861.0
    [m]
    DC
    1864.0
    [m]
    DC
    1867.0
    [m]
    DC
    1870.0
    [m]
    DC
    1880.9
    [m]
    C
    1883.6
    [m]
    C
    1884.3
    [m]
    C
    1894.3
    [m]
    C
    1897.6
    [m]
    C
    1905.5
    [m]
    C
    1908.5
    [m]
    C
    1910.7
    [m]
    C
    1915.5
    [m]
    C
    1919.9
    [m]
    C
    1922.0
    [m]
    C
    1930.0
    [m]
    C
    1931.5
    [m]
    C
    1931.8
    [m]
    C
    1935.0
    [m]
    C
    1938.8
    [m]
    C
    1944.2
    [m]
    C
    1945.5
    [m]
    C
    1951.6
    [m]
    C
    1953.0
    [m]
    C
    1996.9
    [m]
    C
    2000.5
    [m]
    C
    2006.6
    [m]
    C
    2009.9
    [m]
    C
    2014.8
    [m]
    C
    2022.5
    [m]
    C
    2024.7
    [m]
    C
    2033.7
    [m]
    C
    2042.5
    [m]
    C
    2048.4
    [m]
    C

  • Lithostratigraphy

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    FMI HNGS HRLA
    1567
    2135
    MDT
    1575
    2110
    MDT
    1931
    1931
    MDT
    1945
    1945
    MSIP GPIT PEX CBL
    1100
    2140
    MWD - GR RES
    212
    2140
    PEX
    1510
    1950

  • 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
    209.0
    36
    212.7
    0.00
    LOT
    SURF.COND.
    13 3/8
    937.0
    17 1/2
    944.0
    1.45
    LOT
    INTERM.
    9 5/8
    1567.5
    12 1/4
    1573.2
    1.92
    LOT
    OPEN HOLE
    2140.0
    8 1/2
    2140.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    936
    1.14
    15.0
    Performadril
    945
    1.14
    15.0
    Performadril
    1306
    1.24
    18.0
    Performadril
    1573
    1.25
    21.0
    Performadril
    1810
    1.20
    22.0
    Performadril Low Sulphate
    1951
    1.22
    28.0
    Performadril Low Sulphate
    1975
    1.22
    29.0
    Performadril Low Sulphate
    2140
    1.23
    30.0
    Performadril Low Sulphate

  • 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