Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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19.07.2024 - 01:27
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7220/11-2

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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.
    7220/11-2
    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.
    BARENTS 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.
    7220/11-2
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    LN12M01 inline 29260 & crossline 24266
    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.
    Lundin Norway 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.
    1559-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.
    41
    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,
    24.03.2015
    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.
    03.05.2015
    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.
    03.05.2017
    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.
    03.05.2017
    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.
    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.
    GAS
    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.
    TRIASSIC
    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.
    UNDIFFERENTIATED
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    30.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    379.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2050.0
    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).
    2050.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    6.2
    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.
    BASEMENT
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    72° 0' 37.55'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    20° 26' 9.01'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7998765.38
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    687161.60
    UTM zone
    Universal Transverse Mercator zone. Examples of legal values: 31, 32, 33, 34.
    33
    NPDID wellbore
    Norwegian Offshore Directorate's unique id for the wellbore.
    7638
  • Wellbore history

    General
    Well 7220/11-2 was drilled to appraise the 7220/11-1 Alta discovery on the southern part of the Loppa High. The well targeted formations of Permian-Triassic age comparable with the conglomerates encountered in the discovery well. The objectives were to confirm the reservoir model and prove presence of hydrocarbon columns and contacts similar to those established in the discovery well, 7220/11-1. The fluid was expected to be oil with a large gas cap. The gas-oil contact was expected at 1908 m TVD RKB and the free-water level at 1954 m TVD RKB.
    Operations and results
    Appraisal well 7220/11-1 was spudded with the semi-submersible installation Island Innovator on 24 March 2015 and drilled to TD at 2050 m in Basement rocks. A 9 7/8" pilot hole was drilled after installing the 30" conductor casing to 601 m to check for shallow gas. No shallow gas was observed. No significant problem was encountered in the operations. The well was drilled with Seawater and hi-vis pills down to 599 m, and with Aquadril mud from 599 m to TD.
    Top of the target reservoir was encountered at 1864 m. It consists of fine-grained sandstone, conglomeratic in the lower half, with dolomitic cement. It is of Middle Anisian to Olenekian age. It contains a 50-metre gas column in rocks with good to poor reservoir quality. The oil zone was in tight formation. Due to poor reservoir quality, the contacts in the discovery well could not be confirmed, but pressure measurements indicate a common fluid system. Top basement was penetrated at 1954 m. Oil shows were recorded in siltstone and sandstones throughout the Triassic section from Top Kapp Toscana Group and down to top reservoir section. Shows were further recorded throughout the reservoir section and down to 2032 m in the basement rocks.
    Four cores were cut from the interval 1857 to 1962.5 m. Core recovery was 100% for core 1 to 3 and 98.7% for core 4. Depth shift to logs were between -1.5 to -1.6 for all cores. MDT fluid samples were taken at 1866.3 m (gas), 1915.1 m (gas), 1935.5 m (water), and at 1943.4 m (water).
    Due to poor reservoir quality in the oil zone, a geological sidetrack was decided to confirm the presence of an oil leg on the western side of the Alta structure. The well was plugged back for sidetracking on 3 May 2015. It is classified as an oil and gas 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]
    610.00
    2049.00
  • 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
    1857.0
    1884.7
    [m ]
    2
    1884.7
    1912.5
    [m ]
    3
    1912.5
    1940.1
    [m ]
    4
    1940.1
    1962.2
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    105.3
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES
  • Lithostratigraphy

  • Logs

    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CMR XPT ADT
    1846
    2030
    FMI MSIP
    1760
    2046
    MDT
    1866
    1012
    MDT
    1912
    1943
    MDT
    1915
    2000
    MWD-BR REMP BHPR MEC DEN NEU AAC
    1175
    2050
    MWD-GR BHPR MECH
    409
    465
    MWD-GR REMP BHPR MECH AAC
    465
    598
    MWD-NBG BR GR REMP BHPR AAC MECH
    559
    1210
    UBI PEX HRLA NEXT
    1777
    2005
    USIT DCBL
    1074
    1765
    VSP
    445
    2040
    XL ROCK
    1976
    2035
  • 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
    476.0
    36
    479.0
    0.00
    SURF.COND.
    20
    591.3
    26
    599.0
    1.57
    FIT
    PILOT HOLE
    601.0
    9 7/8
    601.0
    0.00
    INTERM.
    13 3/8
    1205.1
    17 1/2
    1212.0
    2.13
    LOT
    INTERM.
    9 5/8
    1770.8
    12 1/4
    1778.0
    1.62
    LOT
    OPEN HOLE
    2050.0
    8 1/2
    2050.0
    0.00
  • Drilling mud

    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    461
    1.03
    2.0
    Water Based
    490
    1.20
    14.0
    Water Based
    521
    1.03
    2.0
    Water Based
    566
    1.40
    20.0
    Water Based
    599
    1.03
    2.0
    Water Based
    1050
    1.16
    11.0
    Water Based
    1355
    1.20
    14.0
    Water Based
    1450
    1.15
    10.0
    Water Based
    1778
    1.20
    14.0
    Water Based
    2050
    1.16
    11.0
    Water Based