Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
22.11.2024 - 09:09
Time of last synchronization with Norwegian Offshore Directorate's internal systems

16/2-17 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.
    16/2-17 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
    Multilateral
    Indicator telling if the parent well is multilateral, meaning it has more than one branch radiating from the main borehole. Example of legal values: YES, NO. See also Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    NO
    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.
    16/2-17
    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.
    1423-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.
    58
    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,
    24.03.2013
    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.
    20.05.2013
    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.
    20.05.2015
    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.
    20.05.2015
    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
    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.
    EARLY 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.
    STATFJORD GP
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    22.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    111.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2052.0
    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).
    2039.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    15.6
    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.
    TRIASSIC
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    58° 48' 15.92'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 31' 46.03'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6518520.01
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    472811.62
    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.
    7085

  • Wellbore history
    >
    General
    Well 16/2-17 S was drilled on the western flank of the Johan Sverdrup Discovery. The main objectives were to investigate the reservoir thickness, quality and facies along the western bounding fault of the Johan Sverdrup Field. The main bounding fault separates the basin to the east where Intra-Draupne Formation sandstone is present in all the wells, and the main Utsira High to west where Intra-Draupne Formation sandstone has not been encountered in the wells nearby.
    Operations and results
    A pilot hole 16/2-U-17 was drilled 25m South-East of the main wellbore to investigate for shallow gas. No gas or shallow water flow were encountered.
    Appraisal well 16/2-17 S was spudded with the semi-submersible installation Ocean Vanguard on 24 March 2013 and drilled to TD at 2052 m (2039 m TVD) in the Triassic Skagerrak Formation. No significant problem was encountered in the operations. The well was drilled with seawater down to 905 m and with Performadril water based mud from 905 m to TD.
    The top of the main reservoir, Draupne Formation, was picked at 1873 m (1859.7 m TVD), 18.3m deeper than prognosed. The reservoir showed excellent reservoir properties and held an 82 m thick oil column down to the oil-water contact in the Statfjord Group at 1957 m (1922 m TVD MSL). A formation gas peak with C2+ hydrocarbons was recorded in the top of the Shetalnad Group, and at 1873 m good oil shows were recorded. Gas generally dropped off down in the Shetland Group. Below the OWC oil shows were described down to 1965 m.
    A total of 164 m core were recovered from seven coring runs covering the Jurassic interval and 21 m TVD into the Triassic Skagerrak Formation. Core recoveries varied between 98.8 and 105.3%. The high recoveries are due to core expansion. MDT fluid samples were taken at 1884.8 m (oil), 1934.5 m (oil), and 1959.7 m (water).
    The well was permanently abandoned on 20 May 2013 as an oil appraisal.
    Testing
    Two Drill Stem Tests were performed.
    DST 1 tested the interval 1929 to 1937 m in the Statfjord Formation reservoir section. It produced 422 Sm3 oil and 14200 Sm3 gas /day through a 40/64" choke. The DST temperature was 77.7 °C.
    DST 2 tested the interval 1875.5 to 1914.5 m, nearly the whole Intra Draupne Formation sandstone section of the reservoir. It produced 910 Sm3 oil and 24300 Sm3 gas /day through a 48/64" choke. The DST temperature was 75.5 °C.

  • 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]
    905.00
    2052.00

  • 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
    1875.0
    1901.8
    [m ]
    2
    1902.0
    1914.4
    [m ]
    3
    1914.4
    1930.4
    [m ]
    4
    1930.4
    1958.4
    [m ]
    5
    1958.5
    1985.6
    [m ]
    6
    1985.7
    2012.3
    [m ]
    7
    2012.6
    2040.6
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    164.9
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • 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
    DST
    1937.00
    1929.00
    OIL
    29.04.2013 - 08:25
    YES
    DST
    1914.50
    1875.50
    OIL
    10.05.2013 - 10:10
    YES
    MDT
    0.00
    1934.50
    OIL
    YES
    MDT
    0.00
    1884.80
    OIL
    YES

  • 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
    195.0
    36
    199.0
    0.00
    SURF.COND.
    13 3/8
    890.0
    17 1/2
    905.0
    1.86
    LOT
    INTERM.
    9 5/8
    1559.0
    12 1/4
    1564.0
    1.45
    FIT
    LINER
    7
    2050.0
    8 1/2
    2051.0
    1.52
    LOT

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    1929
    1937
    17.4
    2.0
    1875
    1914
    20.6
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    77
    2.0
    74
    Drill stem tests (DST)
    Test number
    Oil
    [Sm3/day]
    Gas
    [Sm3/day]
    Oil density
    [g/cm3]
    Gas grav. rel.air
    GOR
    [m3/m3]
    1.0
    470
    15400
    2.0
    1050
    20300

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    ECS CMR ADT
    1561
    2052
    HNGS HRLA PEX
    1561
    2052
    MDT
    1567
    2015
    MSIP FMI
    122
    1913
    MSIP FMI
    1826
    2037
    MWD - ARC PP
    1866
    2047
    MWD - GVR6 ARC PP
    1561
    1875
    MWD - PD XTRA900 ARC TELE
    901
    1561
    MWD - PDX5 ARC PP
    199
    901
    RESOLVE EZSV PLUG
    1925
    1925
    USIT CBL
    134
    810
    USIT CBL
    1016
    1554
    USIT CBL
    1490
    2007
    ZO VSP
    168
    2048

  • Lithostratigraphy

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    199
    1.35
    16.0
    Spud mud
    199
    1.35
    16.0
    Spud mud
    444
    1.35
    18.0
    Spud mud
    613
    1.23
    18.0
    Performadril
    901
    1.35
    26.0
    Performadril
    902
    1.60
    17.0
    Kill Fluid- SW/Bentonite
    1445
    1.24
    18.0
    Performadril
    1561
    1.35
    29.0
    Performadril
    1902
    1.21
    30.0
    Performadril
    1925
    1.24
    18.0
    Performadril
    2052
    1.21
    23.0
    Performadril

  • 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
    FUGRO
    956.0
    [m]
    DC
    FUGRO
    962.0
    [m]
    DC
    FUGRO
    968.0
    [m]
    DC
    FUGRO
    974.0
    [m]
    DC
    FUGRO
    980.0
    [m]
    DC
    FUGRO
    986.0
    [m]
    DC
    FUGRO
    992.0
    [m]
    DC
    FUGRO
    998.0
    [m]
    DC
    FUGRO
    1004.0
    [m]
    DC
    FUGRO
    1010.0
    [m]
    DC
    FUGRO
    1016.0
    [m]
    DC
    FUGRO
    1022.0
    [m]
    DC
    FUGRO
    1028.0
    [m]
    DC
    FUGRO
    1034.0
    [m]
    DC
    FUGRO
    1040.0
    [m]
    DC
    FUGRO
    1046.0
    [m]
    DC
    FUGRO
    1052.0
    [m]
    DC
    FUGRO
    1058.0
    [m]
    DC
    FUGRO
    1064.0
    [m]
    DC
    FUGRO
    1070.0
    [m]
    DC
    FUGRO
    1076.0
    [m]
    DC
    FUGRO
    1082.0
    [m]
    DC
    FUGRO
    1088.0
    [m]
    DC
    FUGRO
    1094.0
    [m]
    DC
    FUGRO
    1100.0
    [m]
    DC
    FUGRO
    1106.0
    [m]
    DC
    FUGRO
    1112.0
    [m]
    DC
    FUGRO
    1118.0
    [m]
    DC
    FUGRO
    1124.0
    [m]
    DC
    FUGRO
    1130.0
    [m]
    DC
    FUGRO
    1136.0
    [m]
    DC
    FUGRO
    1142.0
    [m]
    DC
    FUGRO
    1148.0
    [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
    1804.0
    [m]
    DC
    FUGRO
    1822.0
    [m]
    DC
    FUGRO
    1840.0
    [m]
    DC
    FUGRO
    1858.0
    [m]
    DC
    FUGRO
    1875.2
    [m]
    C
    FUGRO
    1882.5
    [m]
    C
    FUGRO
    1893.5
    [m]
    C
    FUGRO
    1900.5
    [m]
    C
    FUGRO
    1904.3
    [m]
    C
    FUGRO
    1908.6
    [m]
    C
    FUGRO
    1913.3
    [m]
    C
    FUGRO
    1915.5
    [m]
    C
    FUGRO
    1917.9
    [m]
    C
    FUGRO
    1920.6
    [m]
    C
    FUGRO
    1924.0
    [m]
    C
    FUGRO
    1925.0
    [m]
    C
    FUGRO
    1926.2
    [m]
    C
    FUGRO
    1928.0
    [m]
    C
    FUGRO
    1928.7
    [m]
    C
    FUGRO
    1931.6
    [m]
    C
    FUGRO
    1935.8
    [m]
    C
    FUGRO
    1937.0
    [m]
    DC
    FUGRO
    1938.2
    [m]
    C
    FUGRO
    1941.3
    [m]
    C
    FUGRO
    1942.0
    [m]
    DC
    FUGRO
    1944.2
    [m]
    C
    FUGRO
    1949.0
    [m]
    C
    FUGRO
    1951.9
    [m]
    C
    FUGRO
    1953.5
    [m]
    C
    FUGRO
    1955.1
    [m]
    C
    FUGRO
    1957.5
    [m]
    C
    FUGRO
    1958.8
    [m]
    C
    FUGRO
    1961.0
    [m]
    C
    FUGRO
    1961.6
    [m]
    C
    FUGRO
    1965.6
    [m]
    C
    FUGRO
    1968.6
    [m]
    C
    FUGRO
    1972.5
    [m]
    C
    FUGRO
    1973.2
    [m]
    C
    FUGRO
    1979.8
    [m]
    C
    FUGRO
    1983.4
    [m]
    C
    FUGRO
    1986.8
    [m]
    C
    FUGRO
    1990.9
    [m]
    C
    FUGRO
    1995.5
    [m]
    C
    FUGRO
    2002.1
    [m]
    C
    FUGRO
    2006.6
    [m]
    C
    FUGRO
    2007.5
    [m]
    C
    FUGRO
    2010.6
    [m]
    C
    FUGRO
    2012.6
    [m]
    C
    FUGRO
    2017.9
    [m]
    C
    FUGRO
    2021.3
    [m]
    C
    FUGRO
    2029.0
    [m]
    DC
    FUGRO
    2041.0
    [m]
    DC
    FUGRO
    2047.0
    [m]
    DC
    FUGRO
    2052.0
    [m]
    DC
    FUGRO