Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
25.11.2024 - 01:30
Time of last synchronization with Norwegian Offshore Directorate's internal systems

16/2-14

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.
    16/2-14
    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.
    16/2-14
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    LN0902 STR 11 .inline 4000 & xline 3404
    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.
    1405-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.
    65
    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,
    14.09.2012
    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.
    17.11.2012
    Plugged and abondon date
    Date when the P&A-operations of the wellbore was finished, as reported by the operator to the Norwegian Offshore Directorate throught DDRS (Daily Drilling Reporting System). Only applied once pr. wellhead/surface location.
    17.11.2012
    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.
    17.11.2014
    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.
    11.03.2015
    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
    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
    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.
    113.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    1982.0
    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).
    1982.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    4.8
    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.
    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° 50' 25.97'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 31' 2.14'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6522547.56
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    472136.18
    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.
    6898

  • Wellbore history
    General
    Well 16/2-14 was drilled on the Espeværhøgda prospect on the Johan Sverdrup Field on the Utsira High. The main objective was to investigate the reservoir thickness, quality and facies near the crest of the whole Johan Sverdrup structure. The secondary objective was to acquire data in the overburden for field development decisions and planning of future production and injection wells at Johan Sverdrup Field. A third objective was to investigate reservoir presence in the Triassic section (Hegre Group). The fourth objective was to investigate the reservoir quality of the Shetland Group chalk (Ekofisk/Tor Formation).
    Operations and results
    A pilot hole 16/2-U-14 was drilled 30 m south of the main wellbore location to aid in picking core points in the overburden. Appraisal well 16/2-14 was spudded with the semi-submersible installation Ocean Vanguard on 14 September 2012 and drilled to 1210 m where a fish was lost in hole. The hole was cemented back and it was decided to set the 13 3/8 casing shoe. Well 16/2-14 T2 was sidetracked from 16/2-14 below the 13 3/8" casing shoe at 1171 m and drilled to TD at 1982 m in the Triassic Skagerrak Formation. The well was drilled with Seawater down to 608 m and with oil based XP-07 mud from 608 m to TD.
    Good oil shows were recorded at top Ekofisk level from 1565 to 1570 m. Weak shows (from OBM?) were recorded in the Ekofisk chalk from 1570 to 1733 m. The well encountered the target Late Jurassic reservoir sand 18 m deep to prognosis, at 1856 m. The reservoir showed good reservoir properties and contained oil. Top Triassic, the tertiary objective, came in at 1886 m, 11 m deeper than prognosed. There were no shows on the core from the Triassic section (core 7).
    Seven cores were cut. Core 1 was cut from 811 to 820 m in Utsira Formation sandstone, core 2 was cut from 987 to 996 m in Skade Formation sandstone, and core 3 was cut from 1067 to 1076 m in undifferentiated Hordaland Group sandstone and core 4 was cut from 1539 to 1548 m in the Lista Formation mudstone.  Cores 5 to 7 were cut in succession from 1836 to 1904.5 m, covering the interval from lowermost Cretaceous, through the whole reservoir section, and 16 m into the Triassic. MDT water samples were taken at 820.05 m, 820.53 m and 820.98 m in the Utsira Formation and at 1116.53 m in undifferentiated sandstone in the Hordaland Group. Oil samples were taken at 1858 m in the Late Jurassic reservoir sandstone. Fifteen percent contamination of the sampled fluid was estimated.
    The well was permanently abandoned on 17 November 2012 as an oil appraisal.
    Testing
    Injection tests were performed in the plug and abandon phase.

  • 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]
    620.00
    1210.00

  • 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
    811.0
    820.7
    [m ]
    2
    987.0
    991.5
    [m ]
    3
    1067.0
    1074.8
    [m ]
    4
    1539.0
    1547.5
    [m ]
    5
    1836.0
    1849.0
    [m ]
    6
    1849.0
    1876.1
    [m ]
    7
    1877.0
    1904.5
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    98.0
    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
    620.0
    [m]
    DC
    FUGRO
    641.0
    [m]
    DC
    FUGRO
    659.0
    [m]
    DC
    FUGRO
    680.0
    [m]
    DC
    FUGRO
    701.0
    [m]
    DC
    FUGRO
    719.0
    [m]
    DC
    FUGRO
    740.0
    [m]
    DC
    FUGRO
    761.0
    [m]
    DC
    FUGRO
    779.0
    [m]
    DC
    FUGRO
    803.0
    [m]
    DC
    FUGRO
    809.0
    [m]
    DC
    FUGRO
    811.3
    [m]
    C
    FUGRO
    818.0
    [m]
    C
    FUGRO
    819.8
    [m]
    C
    FUGRO
    824.0
    [m]
    DC
    FUGRO
    831.0
    [m]
    DC
    FUGRO
    837.0
    [m]
    DC
    FUGRO
    843.0
    [m]
    DC
    FUGRO
    849.0
    [m]
    DC
    FUGRO
    855.0
    [m]
    DC
    FUGRO
    861.0
    [m]
    DC
    FUGRO
    867.0
    [m]
    DC
    FUGRO
    873.0
    [m]
    DC
    FUGRO
    879.0
    [m]
    DC
    FUGRO
    885.0
    [m]
    DC
    FUGRO
    891.0
    [m]
    DC
    FUGRO
    897.0
    [m]
    DC
    FUGRO
    903.0
    [m]
    DC
    FUGRO
    909.0
    [m]
    DC
    FUGRO
    915.0
    [m]
    DC
    FUGRO
    921.0
    [m]
    DC
    FUGRO
    927.0
    [m]
    DC
    FUGRO
    933.0
    [m]
    DC
    FUGRO
    939.0
    [m]
    DC
    FUGRO
    945.0
    [m]
    DC
    FUGRO
    951.0
    [m]
    DC
    FUGRO
    957.0
    [m]
    DC
    FUGRO
    963.0
    [m]
    DC
    FUGRO
    969.0
    [m]
    DC
    FUGRO
    975.0
    [m]
    DC
    FUGRO
    981.0
    [m]
    DC
    FUGRO
    990.0
    [m]
    C
    FUGRO
    999.0
    [m]
    DC
    FUGRO
    1005.0
    [m]
    DC
    FUGRO
    1011.0
    [m]
    DC
    FUGRO
    1017.0
    [m]
    DC
    FUGRO
    1023.0
    [m]
    DC
    FUGRO
    1029.0
    [m]
    DC
    FUGRO
    1035.0
    [m]
    DC
    FUGRO
    1041.0
    [m]
    DC
    FUGRO
    1047.0
    [m]
    DC
    FUGRO
    1053.0
    [m]
    DC
    FUGRO
    1059.0
    [m]
    DC
    FUGRO
    1065.0
    [m]
    DC
    FUGRO
    1067.1
    [m]
    C
    FUGRO
    1071.0
    [m]
    C
    FUGRO
    1074.8
    [m]
    C
    FUGRO
    1079.0
    [m]
    DC
    FUGRO
    1085.0
    [m]
    DC
    FUGRO
    1091.0
    [m]
    DC
    FUGRO
    1097.0
    [m]
    DC
    FUGRO
    1103.0
    [m]
    DC
    FUGRO
    1109.0
    [m]
    DC
    FUGRO
    1115.0
    [m]
    DC
    FUGRO
    1121.0
    [m]
    DC
    FUGRO
    1127.0
    [m]
    DC
    FUGRO
    1139.0
    [m]
    DC
    FUGRO
    1160.0
    [m]
    DC
    FUGRO
    1181.0
    [m]
    DC
    FUGRO
    1199.0
    [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
    1380.0
    [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
    1539.0
    [m]
    DC
    FUGRO
    1560.0
    [m]
    DC
    FUGRO
    1580.0
    [m]
    DC
    FUGRO
    1601.0
    [m]
    DC
    FUGRO
    1619.0
    [m]
    DC
    FUGRO
    1640.0
    [m]
    DC
    FUGRO
    1661.0
    [m]
    DC
    FUGRO
    1700.0
    [m]
    DC
    FUGRO
    1721.0
    [m]
    DC
    FUGRO
    1739.0
    [m]
    DC
    FUGRO
    1760.0
    [m]
    DC
    FUGRO
    1781.0
    [m]
    DC
    FUGRO
    1793.0
    [m]
    DC
    FUGRO
    1799.0
    [m]
    DC
    FUGRO
    1805.0
    [m]
    DC
    FUGRO
    1811.0
    [m]
    DC
    FUGRO
    1817.0
    [m]
    DC
    FUGRO
    1823.0
    [m]
    DC
    FUGRO
    1829.0
    [m]
    DC
    FUGRO
    1835.0
    [m]
    DC
    FUGRO
    1849.0
    [m]
    C
    FUGRO
    1850.0
    [m]
    C
    FUGRO
    1851.0
    [m]
    C
    FUGRO
    1852.0
    [m]
    C
    FUGRO
    1853.0
    [m]
    C
    FUGRO
    1853.1
    [m]
    C
    FUGRO
    1854.0
    [m]
    C
    FUGRO
    1854.0
    [m]
    C
    FUGRO
    1854.3
    [m]
    C
    FUGRO
    1855.0
    [m]
    C
    FUGRO
    1861.6
    [m]
    C
    FUGRO
    1875.2
    [m]
    C
    FUGRO
    1883.5
    [m]
    C
    FUGRO
    1883.8
    [m]
    C
    FUGRO
    1884.8
    [m]
    C
    FUGRO
    1907.0
    [m]
    DC
    FUGRO
    1913.0
    [m]
    DC
    FUGRO
    1919.0
    [m]
    DC
    FUGRO
    1925.0
    [m]
    DC
    FUGRO
    1931.0
    [m]
    DC
    FUGRO
    1937.0
    [m]
    DC
    FUGRO
    1943.0
    [m]
    DC
    FUGRO
    1949.0
    [m]
    DC
    FUGRO
    1955.0
    [m]
    DC
    FUGRO
    1961.0
    [m]
    DC
    FUGRO
    1967.0
    [m]
    DC
    FUGRO
    1973.0
    [m]
    DC
    FUGRO
    1979.0
    [m]
    DC
    FUGRO

  • Lithostratigraphy

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CMR PEX ECS
    135
    1207
    HNGS ECS PEX AIT
    1572
    1981
    MDT CMR
    1578
    1982
    MDT CMR GR
    796
    1150
    MDT GR
    820
    1117
    MSIP PEX
    1171
    1561
    MWD - ARCVRES TELE
    190
    1067
    MWD - ARCVRES6 TELE
    1570
    1836
    MWD - ARCVRES8 TELE
    1836
    1982
    MWD - PDX5 ARCVRES8 TELE
    1215
    1570
    MWD - TELESCOPE
    1098
    1215
    OBMI MSIP
    1510
    1982
    OBMI MSIP GR
    608
    1207
    USIT CBL
    1057
    1566
    USIT CBL CCL GR
    825
    1165
    VSP GR
    200
    1200
    ZOVSP GR
    1019
    1971

  • 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
    198.0
    36
    198.0
    0.00
    SURF.COND.
    20
    608.0
    26
    608.0
    1.51
    LOT
    INTERM.
    13 3/8
    1171.0
    17 1/2
    1171.0
    1.50
    FIT
    INTERM.
    9 5/8
    1569.0
    12 1/4
    1570.0
    1.58
    LOT
    OPEN HOLE
    1932.0
    8 1/2
    1932.0
    0.00

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    135
    1.60
    22.0
    Kill Fluid- SW/Bentonite
    135
    1.03
    24.0
    PAC RE
    212
    1.03
    24.0
    PAC RE
    550
    1.34
    22.0
    OBM-Low ECD
    609
    1.60
    24.0
    Kill Fluid- SW/Bentonite
    615
    1.30
    17.0
    OBM-Low ECD
    617
    1.30
    18.0
    OBM-Low ECD
    676
    1.31
    21.0
    OBM-Low ECD
    811
    1.30
    21.0
    OBM-Low ECD
    887
    1.30
    20.0
    OBM-Low ECD
    996
    1.30
    22.0
    OBM-Low ECD
    1010
    1.31
    21.0
    OBM-Low ECD
    1076
    1.31
    22.0
    OBM-Low ECD
    1107
    1.31
    19.0
    OBM-Low ECD
    1120
    1.31
    20.0
    OBM-Low ECD
    1183
    1.31
    21.0
    OBM-Low ECD
    1210
    1.31
    22.0
    OBM-Low ECD
    1290
    1.34
    23.0
    OBM-Low ECD
    1570
    1.20
    16.0
    OBM-Low ECD
    1904
    1.30
    21.0
    OBM-Low ECD
    1982
    1.28
    19.0
    OBM-Low ECD