Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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29.04.2024 - 01:33
Time of last synchronization with Norwegian Offshore Directorate's internal systems

16/7-10

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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.
    16/7-10
    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).
    WILDCAT
    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
    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.
    16/7-10
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    inline 4200/xline 4214
    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.
    1359-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.
    67
    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,
    09.07.2011
    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.
    13.09.2011
    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.
    13.09.2013
    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.
    13.09.2013
    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.
    GAS/CONDENSATE
    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.
    YES
    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.
    EARLY PALEOCENE
    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.
    TY FM
    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.
    85.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2514.0
    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).
    2513.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    6.4
    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 CRETACEOUS
    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.
    TOR FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    58° 29' 56.56'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 1' 31.42'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6484832.90
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    443193.93
    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.
    6607

  • Wellbore history
    General
    Well 16/7-10 was drilled on the Theta Prospect in the South Viking Graben in the North Sea, close to the Sleipner field. The prospect was seen as a possible extension of the 16/7-2 discovery in the Ty Formation. The main target was Ty Formation turbidite sands.
    Operations and results
    The semi-submersible installation Ocean Vanguard drilled this well. A 8 1/2" pilot hole 16/7-U-1 was drilled to 610.5 m prior to the main well due to shallow gas warning. At this depth a substantial amount of shallow gas was detected with the ROV sonar. The pilot hole was plugged back. Wildcat well 16/7-10 was spudded on 9 July 2011, 16 m away from the pilot hole. After intermediate wire line logging in the 12 1/4" section, it was not possible to get the 9 5/8" liner to section TD. A technical side-track (16/7-10 T2) was performed from the 16/7-10 well, with a kick-off point at 1916 m, and drilled to final TD at 2514 m in the Late Cretaceous Tor Formation. The well was drilled with sea water and sweeps down to 503 m, with Performadril mud from 503 m to 1151 m, and with XP-07 #14 oil based mud from 1151 m to TD.
    Rocks of Quaternary, Tertiary and Cretaceous age were penetrated. The Ty Formation was encountered with Good reservoir sand at 2348.5 m (2347.5 m TVD), 35.5 m deeper than prognosed. Results of the Theta NE well showed a considerably reduced hydrocarbon column relative to prognosis (2 m gross HC bearing interval vs. 36 m expected). The GWC was found to be at 2349 m (2328 m TVD MSL), the same as encountered at 16/7-2, supporting pressure communication between the two wells. Reservoir parameters were also similar, with Ty Formation 115 m gross reservoir interval, 88 % Net to Gross and 27 % porosity. Hydrocarbon saturation was estimated to 51 %. No oil shows were reported from the well. The use of oil based mud obscured visible shows analysis below 1151 m
    No conventional cores were cut in the well. MDT wire line fluid samples were taken in the Ty Formation at 2348.6 m (2347.6 m TVD; gas/condensate with ca 3% hydrocarbon contamination from mud) and 2383.0 m (2382 m TVD; water).
    The well was permanently abandoned on 13 September 2011 as a minor gas 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]
    510.00
    2270.00

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    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
    1330.0
    [m]
    DC
    FUGRO
    1340.0
    [m]
    DC
    FUGRO
    1370.0
    [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
    1640.0
    [m]
    DC
    FUGRO
    1660.0
    [m]
    DC
    FUGRO
    1680.0
    [m]
    DC
    FUGRO
    1700.0
    [m]
    DC
    FUGRO
    1720.0
    [m]
    DC
    FUGRO
    1740.0
    [m]
    DC
    FUGRO
    1760.0
    [m]
    DC
    FUGRO
    1790.0
    [m]
    DC
    FUGRO
    1800.0
    [m]
    DC
    FUGRO
    1820.0
    [m]
    DC
    FUGRO
    1840.0
    [m]
    DC
    FUGRO
    1860.0
    [m]
    DC
    FUGRO
    1880.0
    [m]
    DC
    FUGRO
    1900.0
    [m]
    DC
    FUGRO
    1920.0
    [m]
    DC
    FUGRO
    1940.0
    [m]
    DC
    FUGRO
    1960.0
    [m]
    DC
    FUGRO
    1980.0
    [m]
    DC
    FUGRO
    2000.0
    [m]
    DC
    FUGRO
    2020.0
    [m]
    DC
    FUGRO
    2040.0
    [m]
    DC
    FUGRO
    2060.0
    [m]
    DC
    FUGRO
    2080.0
    [m]
    DC
    FUGRO
    2100.0
    [m]
    DC
    FUGRO
    2120.0
    [m]
    DC
    FUGRO
    2140.0
    [m]
    DC
    FUGRO
    2160.0
    [m]
    DC
    FUGRO
    2180.0
    [m]
    DC
    FUGRO
    2200.0
    [m]
    DC
    FUGRO
    2220.0
    [m]
    DC
    FUGRO
    2240.0
    [m]
    DC
    FUGRO
    2270.0
    [m]
    DC
    FUGRO
    2280.0
    [m]
    DC
    FUGRO
    2283.0
    [m]
    DC
    FUGRO
    2289.0
    [m]
    DC
    FUGRO
    2295.0
    [m]
    DC
    FUGRO
    2301.0
    [m]
    DC
    FUGRO
    2307.0
    [m]
    DC
    FUGRO
    2313.0
    [m]
    DC
    FUGRO
    2319.0
    [m]
    DC
    FUGRO
    2325.0
    [m]
    DC
    FUGRO
    2331.0
    [m]
    DC
    FUGRO
    2337.0
    [m]
    DC
    FUGRO
    2343.0
    [m]
    DC
    FUGRO
    2349.0
    [m]
    DC
    FUGRO
    2355.0
    [m]
    DC
    FUGRO
    2361.0
    [m]
    DC
    FUGRO
    2367.0
    [m]
    DC
    FUGRO
    2373.0
    [m]
    DC
    FUGRO
    2379.0
    [m]
    DC
    FUGRO
    2385.0
    [m]
    DC
    FUGRO
    2391.0
    [m]
    DC
    FUGRO
    2397.0
    [m]
    DC
    FUGRO
    2403.0
    [m]
    DC
    FUGRO
    2406.0
    [m]
    DC
    FUGRO
    2412.0
    [m]
    DC
    FUGRO
    2418.0
    [m]
    DC
    FUGRO
    2424.0
    [m]
    DC
    FUGRO
    2430.0
    [m]
    DC
    FUGRO
    2436.0
    [m]
    DC
    FUGRO
    2442.0
    [m]
    DC
    FUGRO
    2448.0
    [m]
    DC
    FUGRO
    2454.0
    [m]
    DC
    FUGRO
    2460.0
    [m]
    DC
    FUGRO
    2466.0
    [m]
    DC
    FUGRO
    2484.0
    [m]
    DC
    FUGRO
    2490.0
    [m]
    DC
    FUGRO
    2496.0
    [m]
    DC
    FUGRO
    2502.0
    [m]
    DC
    FUGRO
    2508.0
    [m]
    DC
    FUGRO
    2515.0
    [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
    2348.70
    0.00
    CONDENSATE
    09.02.2011 - 00:00
    NO

  • Lithostratigraphy

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    GPIT MSIP PEX
    503
    1160
    GPIT MSIP PEX GR
    1030
    2265
    GPIT MSIP PEX GR
    2140
    2513
    MDT
    2347
    2347
    MDT
    2490
    2490
    MDT TLC
    2348
    2383
    MWD LWD - ARC ECOS SON TELES
    107
    610
    MWD LWD - ARCVRES6 TELE
    1944
    2283
    MWD LWD - ARCVRS9 TELES
    503
    2278
    MWD LWD - IMPVRES4 VPWD4
    2283
    2514
    PEX GR
    1117
    2185
    USIT
    2000
    2280
    VSP
    1956
    2350
    VSP GR
    520
    2183

  • 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
    172.0
    36
    172.0
    0.00
    LOT
    SURF.COND.
    20
    497.0
    26
    503.0
    1.46
    LOT
    PILOT HOLE
    610.0
    8 1/2
    610.0
    0.00
    LOT
    INTERM.
    13 3/8
    1151.0
    17 1/2
    1151.0
    1.76
    LOT
    INTERM.
    9 5/8
    1905.0
    12 1/4
    2265.0
    0.00
    LOT
    LINER
    7
    2282.0
    8 1/2
    2282.0
    1.35
    LOT
    OPEN HOLE
    2514.0
    6
    2514.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    150
    1.03
    15.0
    Spud Mud
    347
    1.33
    19.0
    Spud Mud
    487
    1.31
    20.0
    Spud Mud
    503
    1.24
    12.0
    Performadril
    1160
    1.30
    28.0
    Performadril
    1180
    1.18
    19.0
    XP-07 - #14
    1906
    1.45
    32.0
    XP-07 - #14
    1944
    1.45
    23.0
    XP-07 - #14
    2072
    1.31
    16.0
    Spud Mud
    2072
    1.30
    15.0
    Spud Mud
    2278
    1.35
    19.0
    XP-07 - #14
    2278
    1.35
    21.0
    XP-07 - #14
    2283
    1.47
    25.0
    XP-07 - #14
    2514
    1.24
    17.0
    XP-07 - #14
    2514
    1.20
    16.0
    XP-07 - #14