Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
12.11.2024 - 01:25
Time of last synchronization with Norwegian Offshore Directorate's internal systems

16/2-9 S

Export: PDF icon PDF

  • General information
    General information
    Attribute Value
    Wellbore name
    Official name of wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    16/2-9 S
    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.
    16/2-9
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    ST09M05-inline 4036 & xline 4012
    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.
    1361-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.
    35
    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,
    21.08.2011
    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.
    24.09.2011
    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.
    24.09.2013
    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.
    24.09.2013
    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.
    DRAUPNE 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.
    116.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2082.0
    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).
    2071.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    17.2
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    85
    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.
    PRE-DEVONIAN
    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.
    BASEMENT
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    58° 54' 46.39'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 26' 22.8'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6530637.43
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    467724.91
    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.
    6615

  • Wellbore history
    General
    Well 16/2-9 S was drilled on the Aldous Major North prospect on the Utsira High in the North Sea. The prospect is separated from the Aldous Major South/Avaldsnes discovery by a North-East trending fault, but was considered as a possible extension of the Aldous Major South. The main objective of the well was to investigate the hydrocarbon potential, reservoir quality and lateral sand distribution in the Late Jurassic Viking Group. The secondary objective of well 16/2-9 S was to explore the hydrocarbon potential in the fractured granitic basement. The third objective of well 16/2-9 S was to investigate the hydrocarbon potential in the Cretaceous age Shetland Chalk Vindballen lead.
    Operations and results
    Wildcat well 16/2-9 S was spudded with the semi-submersible installation Transocean Leader on 21 August 2011and drilled to TD at 2082 m (2070.6 m TVD) into Basement rocks. Neither shallow gas nor shallow water flow was observed, and operations went forth without significant problems. The well was drilled with sea water and hi-vis bentonite pills down to 343 m, with KCl/Polymer/GEM Spec 3 mud from 343 m to 1066 m, with Performadril WBM spec 6a mud from 1066 m to 1725 m, and with Low sulphate Performadril WBM mud from 1725 m to TD.
    Top expected main reservoir, the Draupne Formation, was picked at 1933.5 m. The intra-Draupne reservoir was unusual and consisted of spiculites. It contained oil. The reservoir proved to be considerably thinner and with much poorer reservoir quality than expected and the oil water contact could not be established exactly. However, based on the saturation profile and results from fluid sampling, the OWC was set at 1941.5 m (1930.1 m TVD / 1906.6 m TVD MSL) with the Free Water Level a few meters further down. The secondary and third objectives, the fractured granitic basement and the Shetland chalk respectively, were dry. There were no oil shows observed in the well apart from in the hydrocarbon bearing reservoir section.
    Three cores were taken in the Skagerrak Formation and into the basement at core depths 1952 - 1975.5 m, 1975.5 - 1987 m and 1987.1 - 1991.5 m. The core shifts relative to the logs were 1, 2, and 3 m respectively, for the three cored intervals. MDT wire line fluid samples were taken at 1935.17 m (oil), 1938.2 m (oil), 1941.0 m (water/oil), and at 1941.7 m (oil/water).
    The well was permanently abandoned on 24 September 2011. It is classified as an oil appraisal to the Aldous Major South discovery.
    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]
    350.00
    2082.00

  • 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
    1952.0
    1974.3
    [m ]
    2
    1975.5
    1986.9
    [m ]
    3
    1987.0
    1986.9
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    33.5
    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
    1050.0
    [m]
    DC
    FUGRO
    1070.0
    [m]
    DC
    FUGRO
    1090.0
    [m]
    DC
    FUGRO
    1110.0
    [m]
    DC
    FUGRO
    1130.0
    [m]
    DC
    FUGRO
    1150.0
    [m]
    DC
    FUGRO
    1170.0
    [m]
    DC
    FUGRO
    1190.0
    [m]
    DC
    FUGRO
    1210.0
    [m]
    DC
    FUGRO
    1230.0
    [m]
    DC
    FUGRO
    1250.0
    [m]
    DC
    FUGRO
    1270.0
    [m]
    DC
    FUGRO
    1290.0
    [m]
    DC
    FUGRO
    1310.0
    [m]
    DC
    FUGRO
    1330.0
    [m]
    DC
    FUGRO
    1350.0
    [m]
    DC
    FUGRO
    1370.0
    [m]
    DC
    FUGRO
    1390.0
    [m]
    DC
    FUGRO
    1410.0
    [m]
    DC
    FUGRO
    1430.0
    [m]
    DC
    FUGRO
    1450.0
    [m]
    DC
    FUGRO
    1470.0
    [m]
    DC
    FUGRO
    1490.0
    [m]
    DC
    FUGRO
    1510.0
    [m]
    DC
    FUGRO
    1530.0
    [m]
    DC
    FUGRO
    1550.0
    [m]
    DC
    FUGRO
    1570.0
    [m]
    DC
    FUGRO
    1590.0
    [m]
    DC
    FUGRO
    1610.0
    [m]
    DC
    FUGRO
    1630.0
    [m]
    DC
    FUGRO
    1650.0
    [m]
    DC
    FUGRO
    1670.0
    [m]
    DC
    FUGRO
    1690.0
    [m]
    DC
    FUGRO
    1710.0
    [m]
    DC
    FUGRO
    1724.0
    [m]
    DC
    FUGRO
    1731.0
    [m]
    DC
    FUGRO
    1737.0
    [m]
    DC
    FUGRO
    1743.0
    [m]
    DC
    FUGRO
    1749.0
    [m]
    DC
    FUGRO
    1755.0
    [m]
    DC
    FUGRO
    1761.0
    [m]
    DC
    FUGRO
    1767.0
    [m]
    DC
    FUGRO
    1773.0
    [m]
    DC
    FUGRO
    1779.0
    [m]
    DC
    FUGRO
    1785.0
    [m]
    DC
    FUGRO
    1791.0
    [m]
    DC
    FUGRO
    1797.0
    [m]
    DC
    FUGRO
    1803.0
    [m]
    DC
    FUGRO
    1809.0
    [m]
    DC
    FUGRO
    1827.0
    [m]
    DC
    FUGRO
    1851.0
    [m]
    DC
    FUGRO
    1857.0
    [m]
    DC
    FUGRO
    1863.0
    [m]
    DC
    FUGRO
    1869.0
    [m]
    DC
    FUGRO
    1875.0
    [m]
    DC
    FUGRO
    1881.0
    [m]
    DC
    FUGRO
    1887.0
    [m]
    DC
    FUGRO
    1893.0
    [m]
    DC
    FUGRO
    1899.0
    [m]
    DC
    FUGRO
    1902.0
    [m]
    DC
    FUGRO
    1908.0
    [m]
    DC
    FUGRO
    1914.0
    [m]
    DC
    FUGRO
    1920.0
    [m]
    DC
    FUGRO
    1926.0
    [m]
    DC
    FUGRO
    1932.0
    [m]
    DC
    FUGRO
    1938.0
    [m]
    DC
    FUGRO
    1944.0
    [m]
    DC
    FUGRO
    1953.0
    [m]
    DC
    FUGRO
    1959.0
    [m]
    DC
    FUGRO
    1965.0
    [m]
    DC
    FUGRO
    1971.0
    [m]
    DC
    FUGRO
    1977.0
    [m]
    DC
    FUGRO
    1983.0
    [m]
    DC
    FUGRO
    1989.0
    [m]
    DC
    FUGRO
    1995.0
    [m]
    DC
    FUGRO
    2001.0
    [m]
    DC
    FUGRO
    2007.0
    [m]
    DC
    FUGRO
    2013.0
    [m]
    DC
    FUGRO
    2019.0
    [m]
    DC
    FUGRO
    2025.0
    [m]
    DC
    FUGRO
    2031.0
    [m]
    DC
    FUGRO
    2037.0
    [m]
    DC
    FUGRO
    2043.0
    [m]
    DC
    FUGRO
    2055.0
    [m]
    DC
    FUGRO
    2061.0
    [m]
    DC
    FUGRO
    2073.0
    [m]
    DC
    FUGRO
    2079.0
    [m]
    DC
    FUGRO

  • Oil samples at the Norwegian Offshore Directorate
    Oil samples at the Norwegian Offshore Directorate
    Test type
    Bottle number
    Top depth
    MD [m]
    Bottom depth
    MD [m]
    Fluid type
    Test time
    Samples available
    MDT
    1935.20
    0.00
    OIL
    11.03.2011 - 00:00
    YES
    MDT
    1938.20
    0.00
    OIL
    11.03.2011 - 00:00
    YES
    MDT
    1941.70
    0.00
    OIL
    11.03.2011 - 00:00
    YES

  • Lithostratigraphy

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    FMI HNGS HRLA
    1724
    2074
    MDT
    1934
    1965
    MDT
    1935
    1995
    MSIP PEX
    1540
    2075
    MWD - ARC PP
    216
    1066
    MWD - GVR ARC PUP
    1724
    2083
    MWD - PDX5 ARC PUP
    1066
    1724
    MWD - PP
    138
    216
    USIT CBL
    351
    980
    USIT CBL
    1529
    1720
    VSI-1
    1648
    2072
    VSI-4
    151
    1709

  • 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
    SURF.COND.
    20
    332.0
    26
    343.0
    1.41
    LOT
    INTERM.
    13 3/8
    1059.0
    17 1/2
    1066.0
    1.74
    LOT
    INTERM.
    9 5/8
    1724.0
    12 1/4
    1725.0
    2.04
    LOT
    OPEN HOLE
    2082.0
    8 1/2
    2082.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    614
    1.25
    20.0
    KCl/Polymer/GEM
    1066
    1.25
    18.0
    KCl/Polymer/GEM
    1067
    1.23
    20.0
    Performadril
    1361
    1.20
    22.0
    Performadril Low Sulphate
    1724
    1.28
    14.0
    Performadril
    1725
    1.20
    26.0
    Performadril
    1725
    1.29
    31.0
    Performadril
    1987
    1.20
    23.0
    Performadril Low Sulphate
    2082
    1.20
    22.0
    Performadril Low Sulphate
    2982
    1.20
    24.0
    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