Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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sodir.no          Norsk
22.12.2024 - 01:25
Time of last synchronization with Norwegian Offshore Directorate's internal systems

16/7-11

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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.
    16/7-11
    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
    Well name
    Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    16/7-11
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    ST09M13 inline 4400 & xline 3166
    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.
    1567-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.
    24
    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,
    12.08.2015
    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.
    04.09.2015
    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.
    04.09.2017
    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.
    04.09.2017
    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.
    DRY
    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
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    25.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    80.5
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2650.0
    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).
    2650.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    1.9
    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° 22' 52.95'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 4' 5.04'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6471696.43
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    445499.44
    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.
    7750

  • Wellbore history
    General
    Well 16/7-11 was drilled to test the Knappen prospect on the Sleipner Terrace in the North Sea. The primary objective was to test the hydrocarbon potential in the Skagerrak Formation.
    Operations and results
    Wildcat well 16/7-11 was spudded with the semi-submersible installation Songa Trym on 12 August 2015 and drilled to TD at 2650 m in the Early Triassic Skagerrak Formation. No significant problem was encountered in the operations but shallow gas was observed at 613 and 630 m. The well was drilled with Spud mud down to 575 m, with Glydril mud from 575 to 1560 m and with EMS-4400 oil based mud from 1560 m to TD.
    Top Skagerrak Formation was encountered at 2546 m. The Skagerrak Formation reservoir was found to be dry based on logs, gas response, and lack of hydrocarbon shows in cuttings.
    No cores were cut. No logs were run on wire line. No fluid sample was taken.
    During the plug and abandon, gas bubbles were observed migrating from the wellhead after pulling out the BOP.
    This gas was suspected to come from the shallow gas zone at 630m MD. Total time spent for P&A operations including sealing off the gas leak was 8.4 days.
    The well was permanently abandoned on 4 September 2015 as a dry 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]
    580.00
    2650.80

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    580.0
    [m]
    DC
    ROBERTSO
    600.0
    [m]
    DC
    ROBERT
    620.0
    [m]
    DC
    ROBERT
    640.0
    [m]
    DC
    ROBERT
    660.0
    [m]
    DC
    ROBERT
    680.0
    [m]
    DC
    ROBERT
    700.0
    [m]
    DC
    ROBERT
    720.0
    [m]
    DC
    ROBERT
    740.0
    [m]
    DC
    ROBERT
    760.0
    [m]
    DC
    ROBERT
    780.0
    [m]
    DC
    ROBERT
    800.0
    [m]
    DC
    ROBERT
    820.0
    [m]
    DC
    ROBERT
    840.0
    [m]
    DC
    ROBERT
    860.0
    [m]
    DC
    ROBERT
    880.0
    [m]
    DC
    ROBERT
    900.0
    [m]
    DC
    ROBERT
    920.0
    [m]
    DC
    ROBERT
    940.0
    [m]
    DC
    ROBERT
    960.0
    [m]
    DC
    ROBERT
    1000.0
    [m]
    DC
    ROBERT
    1020.0
    [m]
    DC
    ROBERT
    1040.0
    [m]
    DC
    ROBERT
    1060.0
    [m]
    DC
    ROBERT
    1080.0
    [m]
    DC
    ROBERT
    1100.0
    [m]
    DC
    ROBERT
    1120.0
    [m]
    DC
    ROBERT
    1140.0
    [m]
    DC
    ROBERT
    1160.0
    [m]
    DC
    ROBERT
    1180.0
    [m]
    DC
    ROBERT
    1200.0
    [m]
    DC
    ROBERT
    1220.0
    [m]
    DC
    ROBERT
    1240.0
    [m]
    DC
    ROBERT
    1260.0
    [m]
    DC
    ROBERT
    1280.0
    [m]
    DC
    ROBERT
    1300.0
    [m]
    DC
    ROBERT
    1320.0
    [m]
    DC
    ROBERT
    1340.0
    [m]
    DC
    ROBERT
    1360.0
    [m]
    DC
    ROBERT
    1380.0
    [m]
    DC
    ROBERT
    1400.0
    [m]
    DC
    ROBERT
    1420.0
    [m]
    DC
    ROBERT
    1440.0
    [m]
    DC
    ROBERT
    1460.0
    [m]
    DC
    ROBERT
    1480.0
    [m]
    DC
    ROBERT
    1500.0
    [m]
    DC
    ROBERT
    1520.0
    [m]
    DC
    ROBERT
    1540.0
    [m]
    DC
    ROBERT
    1560.0
    [m]
    DC
    ROBERT
    1580.0
    [m]
    DC
    ROBERT
    1600.0
    [m]
    DC
    ROBERT
    1620.0
    [m]
    DC
    ROBERT
    1640.0
    [m]
    DC
    ROBERT
    1660.0
    [m]
    DC
    ROBERT
    1680.0
    [m]
    DC
    ROBERT
    1700.0
    [m]
    DC
    ROBERT
    1720.0
    [m]
    DC
    ROBERT
    1740.0
    [m]
    DC
    ROBERT
    1760.0
    [m]
    DC
    ROBERT
    1780.0
    [m]
    DC
    ROBERT
    1800.0
    [m]
    DC
    ROBERT
    1820.0
    [m]
    DC
    ROBERT
    1840.0
    [m]
    DC
    ROBERT
    1860.0
    [m]
    DC
    ROBERT
    1880.0
    [m]
    DC
    ROBERT
    1900.0
    [m]
    DC
    ROBERT
    1920.0
    [m]
    DC
    ROBERT
    1940.0
    [m]
    DC
    ROBERT
    1960.0
    [m]
    DC
    ROBERT
    1980.0
    [m]
    DC
    ROBERT
    2000.0
    [m]
    DC
    ROBERT
    2020.0
    [m]
    DC
    ROBERT
    2040.0
    [m]
    DC
    ROBERT
    2060.0
    [m]
    DC
    ROBERT
    2080.0
    [m]
    DC
    ROBERT
    2100.0
    [m]
    DC
    ROBERT
    2120.0
    [m]
    DC
    ROBERT
    2140.0
    [m]
    DC
    ROBERT
    2160.0
    [m]
    DC
    ROBERT
    2180.0
    [m]
    DC
    ROBERT
    2200.0
    [m]
    DC
    ROBERT
    2220.0
    [m]
    DC
    ROBERT
    2240.0
    [m]
    DC
    ROBERT
    2260.0
    [m]
    DC
    ROBERT
    2280.0
    [m]
    DC
    ROBERT
    2300.0
    [m]
    DC
    ROBERT
    2320.0
    [m]
    DC
    ROBERT
    2340.0
    [m]
    DC
    ROBERT
    2360.0
    [m]
    DC
    ROBERT
    2380.0
    [m]
    DC
    ROBERT
    2400.0
    [m]
    DC
    ROBERT
    2420.0
    [m]
    DC
    ROBERT
    2480.0
    [m]
    DC
    ROBERT
    2486.0
    [m]
    DC
    ROBERT
    2492.0
    [m]
    DC
    ROBERT
    2498.0
    [m]
    DC
    ROBERT
    2510.0
    [m]
    DC
    ROBERT
    2516.0
    [m]
    DC
    ROBERT
    2522.0
    [m]
    DC
    ROBERT

  • Lithostratigraphy

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    ARC9 TELE950
    156
    1563
    PDX5 ARCVIS675 TELE625
    1553
    2650
    TELE950
    105
    156

  • 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
    155.5
    36
    155.5
    0.00
    SURF.COND.
    20
    566.8
    26
    575.0
    1.43
    FIT
    INTERM.
    13 3/8
    1552.7
    17 1/2
    1560.0
    1.71
    LOT
    OPEN HOLE
    2650.0
    8 1/2
    2650.0
    0.00

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    630
    1.28
    12.0
    Glydril
    1260
    1.26
    15.0
    Glydril
    1560
    1.30
    15.0
    Glydril
    1560
    1.34
    20.0
    EMS 4400
    1730
    1.34
    20.0
    EMS 4400
    2274
    1.39
    23.0
    EMS 4400
    2651
    1.39
    24.0
    EMS 4400