Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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03.11.2024 - 01:26
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16/2-10

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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.
    16/2-10
    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.
    16/2-10
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    LN0902R10 inline 3994 & xline 3578
    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.
    1375-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.
    32
    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,
    27.09.2011
    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.
    28.10.2011
    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.
    28.10.2013
    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.
    28.10.2013
    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.
    APPRAISAL
    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.
    115.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2090.0
    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).
    2090.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    0.7
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    94
    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° 51' 16.08'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 32' 37.5'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6524086.78
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    473675.68
    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.
    6715

  • Wellbore history
    General
    Well 16/2-10 was drilled on the Utsira High in the North Sea to appraise the northern part of the Aldous Major Discovery in a segment called Espevær. The main objective was to investigate the hydrocarbon potential and the
    reservoir quality and lateral sand distribution in Late Jurassic sandstones in the Draupne Formation of the Viking Group, and the Hugin and Sleipner Formations of the Vestland Group. The secondary well objective was to explore the reservoir properties in the Triassic age Skagerrak Formation. The third objective was to investigate the hydrocarbon potential in the Cretaceous chalk of the Shetland Group.
    Operations and results
    A 9 7/8" pilot hole 16/2-U-6 was drilled to check for shallow gas down to setting depth for the 20" casing. No sign of shallow gas or shallow water flow was seen on the logs nor observed by the ROV.
    Appraisal well 16/2-10 was spudded with the semi-submersible installation Transocean Leader on 27 September 2011 and drilled to TD at 2090 m in the Late Triassic Skagerrak Formation. No significant problem was encountered in the operations. The well was drilled with sea water down to 463 m and with water based Performadril mud with 3-4% glycol from 463 m to TD.
    Well 16/2-10 penetrated sediments of Cenozoic, Cretaceous, Jurassic and Triassic age. Top of the Intra Draupne Formation sandstones, came in at 1892 m. An oil column of 66 meters was found in these sandstones and the underlying sandstones of the Middle Jurassic Hugin Formation. The free water level was established at 1957.7 m (1934.2 m TVD MSL) as confirmed by logs, cores, pressure data and fluid samples. This is deeper than in the 16/2-8 discovery well, where the free water level was found at 1920.7 m. The Triassic Skagerrak Formation was water wet. There were no sign of hydrocarbons in the Shetland Group. Oil shows were recorded from 1890 m to 1953 m.
    Four cores were cut from 1889.5 m in the Åsgard Formation to base Hugin Formation at 1962 m. Reservoir fluid samples were obtained in 3 MDT runs at 7 depths: 1893.5 m (oil), 1927.0 m (oil), 1935.5 m (oil), 1935.7 m (oil), 1955 m (oil and some water), 1961 m (water), and 1966 m (water).
    The well was permanently abandoned on 28 October 2011 as an oil appraisal well.
    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]
    460.00
    2089.00

  • 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
    1889.5
    1894.7
    [m ]
    2
    1897.4
    1912.5
    [m ]
    3
    1912.5
    1939.6
    [m ]
    4
    1939.6
    1962.0
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    69.9
    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
    460.0
    [m]
    DC
    FUGRO
    480.0
    [m]
    DC
    FUGRO
    500.0
    [m]
    DC
    FUGRO
    520.0
    [m]
    DC
    FUGRO
    540.0
    [m]
    DC
    FUGRO
    560.0
    [m]
    DC
    FUGRO
    580.0
    [m]
    DC
    FUGRO
    600.0
    [m]
    DC
    FUGRO
    620.0
    [m]
    DC
    FUGRO
    640.0
    [m]
    DC
    FUGRO
    660.0
    [m]
    DC
    FUGRO
    680.0
    [m]
    DC
    FUGRO
    700.0
    [m]
    DC
    FUGRO
    720.0
    [m]
    DC
    FUGRO
    740.0
    [m]
    DC
    FUGRO
    760.0
    [m]
    DC
    FUGRO
    780.0
    [m]
    DC
    FUGRO
    800.0
    [m]
    DC
    FUGRO
    820.0
    [m]
    DC
    FUGRO
    840.0
    [m]
    DC
    FUGRO
    860.0
    [m]
    DC
    FUGRO
    880.0
    [m]
    DC
    FUGRO
    900.0
    [m]
    DC
    FUGRO
    920.0
    [m]
    DC
    FUGRO
    940.0
    [m]
    DC
    FUGRO
    960.0
    [m]
    DC
    FUGRO
    980.0
    [m]
    DC
    FUGRO
    1000.0
    [m]
    DC
    FUGRO
    1020.0
    [m]
    DC
    FUGRO
    1040.0
    [m]
    DC
    FUGRO
    1060.0
    [m]
    DC
    FUGRO
    1080.0
    [m]
    DC
    FUGRO
    1100.0
    [m]
    DC
    FUGRO
    1120.0
    [m]
    DC
    FUGRO
    1140.0
    [m]
    DC
    FUGRO
    1160.0
    [m]
    DC
    FUGRO
    1180.0
    [m]
    DC
    FUGRO
    1200.0
    [m]
    DC
    FUGRO
    1220.0
    [m]
    DC
    FUGRO
    1240.0
    [m]
    DC
    FUGRO
    1260.0
    [m]
    DC
    FUGRO
    1280.0
    [m]
    DC
    FUGRO
    1300.0
    [m]
    DC
    FUGRO
    1320.0
    [m]
    DC
    FUGRO
    1340.0
    [m]
    DC
    FUGRO
    1360.0
    [m]
    DC
    FUGRO
    1390.0
    [m]
    DC
    FUGRO
    1400.0
    [m]
    DC
    FUGRO
    1420.0
    [m]
    DC
    FUGRO
    1440.0
    [m]
    DC
    FUGRO
    1460.0
    [m]
    DC
    FUGRO
    1480.0
    [m]
    DC
    FUGRO
    1500.0
    [m]
    DC
    FUGRO
    1520.0
    [m]
    DC
    FUGRO
    1540.0
    [m]
    DC
    FUGRO
    1560.0
    [m]
    DC
    FUGRO
    1580.0
    [m]
    DC
    FUGRO
    1600.0
    [m]
    DC
    FUGRO
    1620.0
    [m]
    DC
    FUGRO
    1633.0
    [m]
    DC
    FUGRO
    1639.0
    [m]
    DC
    FUGRO
    1657.0
    [m]
    DC
    FUGRO
    1729.0
    [m]
    DC
    FUGRO
    1747.0
    [m]
    DC
    FUGRO
    1759.0
    [m]
    DC
    FUGRO
    1765.0
    [m]
    DC
    FUGRO
    1771.0
    [m]
    DC
    FUGRO
    1777.0
    [m]
    DC
    FUGRO
    1783.0
    [m]
    DC
    FUGRO
    1789.0
    [m]
    DC
    FUGRO
    1795.0
    [m]
    DC
    FUGRO
    1801.0
    [m]
    DC
    FUGRO
    1807.0
    [m]
    DC
    FUGRO
    1813.0
    [m]
    DC
    FUGRO
    1819.0
    [m]
    DC
    FUGRO
    1825.0
    [m]
    DC
    FUGRO
    1831.0
    [m]
    DC
    FUGRO
    1837.0
    [m]
    DC
    FUGRO
    1882.0
    [m]
    DC
    FUGRO
    1885.0
    [m]
    DC
    FUGRO
    1888.0
    [m]
    DC
    FUGRO
    1898.6
    [m]
    CC
    FUGRO
    1904.2
    [m]
    CC
    FUGRO
    1906.6
    [m]
    CC
    FUGRO
    1911.2
    [m]
    CC
    FUGRO
    1922.0
    [m]
    CC
    FUGRO
    1928.9
    [m]
    CC
    FUGRO
    1929.9
    [m]
    CC
    FUGRO
    1930.1
    [m]
    CC
    FUGRO
    1931.0
    [m]
    CC
    FUGRO
    1940.0
    [m]
    CC
    FUGRO
    1944.9
    [m]
    CC
    FUGRO
    1948.1
    [m]
    CC
    FUGRO
    1952.6
    [m]
    CC
    FUGRO
    1959.0
    [m]
    CC
    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
    1927.00
    0.00
    OIL
    21.10.2011 - 00:00
    YES
    MDT
    1935.50
    0.00
    OIL
    19.10.2011 - 00:00
    YES
    MDT
    1893.50
    0.00
    OIL
    19.10.2011 - 00:00
    YES

  • Lithostratigraphy

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CMR ECS GR
    1631
    2092
    FMI HNGS HRLA
    1631
    2092
    LWD MWD - ARCRES6 ADN
    1889
    2090
    LWD MWD - ARCRES8 PP
    138
    455
    LWD MWD - ARCRES9 TELE
    455
    948
    LWD MWD - GVR ARCRES8 TELE
    948
    1631
    LWD MWD - RAB6 ECO TELE
    1631
    1889
    MDT HC
    1893
    1966
    MDT PS
    1893
    1966
    MDT QWS
    1955
    1961
    MSIP GPIT PEX CBL
    1025
    2078
    USIT GR
    1250
    1630
    VSI4 GR
    1243
    2082

  • 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
    212.2
    36
    213.0
    0.00
    LOT
    SURF.COND.
    20
    449.0
    26
    463.0
    1.53
    LOT
    INTERM.
    13 3/8
    942.0
    17 1/2
    948.0
    0.00
    LOT
    INTERM.
    9 5/8
    1630.0
    12 1/4
    1631.0
    1.57
    LOT
    OPEN HOLE
    2090.0
    8 1/2
    2090.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    139
    1.60
    24.0
    Kill Fluid- SW/Bentonite
    216
    1.60
    24.0
    Kill Fluid- SW/Bentonite
    300
    1.35
    22.0
    Spud Mud
    513
    1.25
    16.0
    Performadril
    872
    1.25
    26.0
    Performadril
    1045
    1.35
    28.0
    Performadril
    1631
    1.37
    51.0
    Performadril
    2090
    1.22
    23.0
    Performadril

  • 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
    0.21