Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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15.07.2024 - 01:28
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7220/11-2 A

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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 A
    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.
    1577-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.
    43
    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,
    03.05.2015
    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.
    14.06.2015
    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.
    14.06.2017
    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.
    14.06.2017
    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.
    OIL/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).
    2121.0
    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).
    2071.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    19.3
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    73
    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.
    7693
  • Wellbore history

    General
    Well 7220/11-2 A is a geological sidetrack to well 7220/11-2. Both wells were drilled to appraise the 7220/11-1 Alta discovery. The main well found gas in Early Triassic sandstones and conglomerate, but no producible oil due to tight formation in the lower part of the reservoir. The objective of 7220/11-2 A was to investigate reservoir quality and confirm the presence of an oil leg on the western flank of the Alta structure.
    Operations and results
    Appraisal well 7220/11-2 A was kicked off at 635 m in the main well on 3 May 2015. It was drilled with the semi-submersible installation Island Innovator to TD at 2121 m (2071 m TVD) in basement rocks. No significant problem was encountered in the operations. The well was drilled with Aquadril mud from kick-off to TD.
    Top of the target reservoir was encountered at 1951.8 m (1901.7 m TVD). The reservoir consists of Early Triassic sandstone and conglomerates, similar as in the main well. The reservoir was oil and gas bearing. The contacts in the 7220/11-1 discovery well were not confirmed; however, pressure points indicated a common fluid system with the main well and with 7220/11-1. The thickness of the reservoir is 102 m TVD, ca 13 m thicker than in the main well. Between base reservoir and top basement, well 7220/11-2 A penetrated a 14 m thick sequence with marl, claystone and dolomite, possibly belonging to the Gipsdalen Group. Oil shows were similar as in the main well bore: on siltstone and sandstones from top Toscana Group to top reservoir, throughout the reservoir, and down to 2079 m in the basement.
    Six conventional cores were cut in the interval 1926.6 to 2048.66 m (125.9 m). Recovery for core 1 was 99%, for the remaining cores recovery was 100%. The core-log depth shift is -2.19 m for all cores. MDT fluid samples were taken at 1967.15 m (oil), 1989.71 m (oil), 2008.72 m (water), and 2030.11 m (water)
    The well was permanently abandoned on 14 June 2015 as an oil and gas appraisal well.
    Testing
    A production test was performed from the interval 1965.2 to 1997.37 m. The test produced 136 Sm3 oil and 18500 Sm3 gas /day through a 24/64" choke in the main flow. The flowing temperature was 68.8 °C, measured at 1952.6 m.
  • 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
    2121.00
  • 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
    1926.6
    1936.4
    [m ]
    2
    1936.5
    1937.8
    [m ]
    3
    1937.8
    1965.6
    [m ]
    4
    1965.6
    1993.6
    [m ]
    5
    1993.6
    2021.1
    [m ]
    6
    2021.1
    2048.6
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    121.9
    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
    MDT
    0.00
    0.00
    OIL
    04.06.2015 - 00:00
    YES
    MDT
    0.00
    0.00
    OIL
    04.06.2015 - 00:00
    YES
  • Lithostratigraphy

  • Drill stem tests (DST)

    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    1965
    1997
    9.5
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    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
    136
    24000
    141
  • Logs

    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CMR XPT ADT
    1911
    2110
    FMI MSIP
    409
    2119
    MDT
    1928
    2052
    MWD - BR GR REMP BHPR MECH AAC
    566
    1222
    MWD - GR BHPR MECH
    409
    465
    MWD - GR REMP BHPR MECH DEN NEU
    1158
    2121
    MWD - GR REMP BHPR MECH AAC
    456
    598
    UBI PEX HRLA HNGS NEXT
    1851
    2113
    USIT
    1790
    2120
  • 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
    1215.2
    17 1/2
    1222.0
    1.80
    FIT
    INTERM.
    9 5/8
    1853.0
    12 1/4
    1860.0
    1.68
    LOT
    LINER
    7
    2120.0
    8 1/2
    2121.0
    0.00
  • Drilling mud

    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    1026
    1.23
    23.0
    Water Based
    1222
    1.25
    19.0
    Water Based
    1494
    1.23
    11.0
    Water Based
    1729
    1.23
    16.0
    Water Based
    1865
    1.15
    9.0
    Water Based
    1938
    1.15
    12.0
    Water Based
    2120
    1.14
    1.0
    Water Based
    2121
    1.15
    15.0
    Water Based