Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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21.11.2024 - 01:28
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7220/11-3 AR

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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.
    7220/11-3 AR
    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.
    7220/11-3
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    LN12M01 inline 29006 xline 24350
    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.
    1621-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.
    77
    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,
    27.07.2016
    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.
    10.10.2016
    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.
    10.10.2016
    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.
    10.10.2018
    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.
    10.10.2018
    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.
    YES
    Reentry activity
    Reason for reentry of the wellbore. Only relevant for exploration wellbores. Example of legal values: DRILLING, DRILLING/PLUGGING, LOGGING, PLUGGING, TESTING, TESTING/PLUGGING.
    DRILLING/TESTING/PLUGGING
    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.
    LATE 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.
    KLAPPMYSS FM
    2nd level with HC, age
    Age of lithostratigraphic unit, 2nd level, where hydrocarbons were encountered. Examples of legal values: CRETACEOUS, EARLY CRETACEOUS, LATE JURASSIC, EOCENE.
    EARLY TRIASSIC
    2nd level with HC, formation
    Name of lithostartigraphic unit, 2nd 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.
    NO FORMAL NAME
    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.
    397.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2600.0
    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).
    2414.1
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    41.3
    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.
    CARBONIFEROUS
    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.
    UGLE FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    72° 1' 12.62'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    20° 31' 41.23'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    8000137.25
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    690231.43
    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.
    7959

  • Wellbore history
    Wellbore history
    General
    Re-entry well 7220/11-3 AR was drilled to appraise the Alta Discovery on the southern part of the Loppa High in the Barents Sea. The objectives were to deepen the 7220/11-3 A well bore to Permian and Carboniferous strata, to evaluate the reservoir properties of Permian and Carboniferous carbonates (Ørn and Falk Formations), and to test the productivity of the Permo-Triassic Alta reservoir by a drill stem test.
    Operations and results
    Appraisal well 7220/11-3 A was re-entered with the semi-submersible installation Leiv Eiriksson on 27 June 2016. The extension was drilled as a 6-inch hole from 2130 m to a total depth of 2600 m (2414 m TVD) in the Carboniferous Ugle Formation. When drilling at 2246 m in fractured carbonates mud losses occurred. This caused 74 hrs NPT. During P&A the drill string parted when cutting and retrieving wellhead. This caused 43.5 hrs NPT. The well was drilled with KCl/Polymer/GEM mud from 2130 to TD.
    The re-entry was drilled entirely within the water zone below the Alta reservoir. MDT pore pressure measurements confirmed the expected Permian water pressures and gradient previously seen in the 7220/11-1 discovery. The pressure points further confirmed a Free Water Level of 1924 m TVD MSL as found in well 7220/11-3 A. Traces of residual oil were observed in the dolomites and limestones from below the FWL (2089 m MD RKB for Leiv Eiriksson), down to approximately 2205 m.
    Nine conventional cores were cut in four different coring runs in the interval 2133 to 2298.6 m. In total, 24.9 m was recovered. MDT fluid samples were acquired from two sampling stations in the water zone, one at 2161.1 m in the Ørn Formation and one at 2337.0 m in the Falk Formation. All samples contained water with minor dissolved gas.
    The well was permanently abandoned on 10 October 2016 as an oil and gas appraisal well.
    Testing
    Three drill stem tests were performed in the well.
    DST1 was a water injection test in the interval 2330 to 2360 m in the Falk Formation. The test performed with an injection rate of 800 m3 seawater/day
    DST2 was a water injection test in the interval 2150 to 2180 m in the Ørn Formation. The test performed with an injection rate of 2900 m3 seawater/day
    DST3 tested the interval 2012 to 2020 m in the Klappmyss Formation. This test produced 595,000 Sm3 gas per day through a 64/64 inch choke.
    >

  • 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]
    2133.00
    2600.00

  • 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
    2133.0
    2134.5
    [m ]
    2
    2140.5
    2140.9
    [m ]
    3
    2143.0
    2147.2
    [m ]
    4
    2149.2
    2150.8
    [m ]
    5
    2186.0
    2193.3
    [m ]
    6
    2193.3
    2196.3
    [m ]
    7
    2196.8
    2202.5
    [m ]
    8
    2297.0
    2297.6
    [m ]
    9
    2297.8
    2298.5
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    24.9
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Lithostratigraphy

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    3.0
    2012
    2020
    25.4
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    3.0
    Drill stem tests (DST)
    Test number
    Oil
    [Sm3/day]
    Gas
    [Sm3/day]
    Oil density
    [g/cm3]
    Gas grav. rel.air
    GOR
    [m3/m3]
    3.0
    595000

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    FMI MSIP
    2144
    2593
    HRLA PEX ADT GR
    2127
    2592
    MDT
    2161
    2337
    MSCT GR
    2138
    2579
    MWD - OTK BCPM2
    2130
    2133
    MWD - OTK BCPM2 LTK STK
    2091
    2596
    VSI
    2115
    2161
    VSI
    2115
    2161
    XPT CMR NEXT GR
    2127
    2573

  • 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
    488.6
    36
    489.0
    0.00
    SURF.COND.
    20
    585.1
    26
    593.0
    1.41
    LOT
    PILOT HOLE
    593.0
    9 7/8
    593.0
    0.00
    INTERM.
    13 3/8
    1072.3
    17 1/2
    1080.0
    1.40
    LOT
    INTERM.
    9 5/8
    1899.7
    12 1/4
    1908.0
    1.45
    LOT
    LINER
    7
    2128.5
    8 1/2
    2130.0
    0.00
    2133.0
    0.0
    1.35
    FIT
    LINER
    5
    2504.8
    6
    0.0
    0.00
    OPEN HOLE
    2600.0
    6
    2600.0
    0.00

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    926
    1.21
    15.0
    KCL/Gem
    926
    1.15
    12.0
    KCL/Gem
    1609
    1.21
    15.0
    KCL/Gem
    1609
    1.20
    12.0
    KCL/Gem
    1633
    1.14
    14.0
    KCL/Gem
    2138
    1.14
    14.0
    WBM
    2145
    1.14
    18.0
    KCL/Polymer/Gem
    2297
    1.14
    15.0
    KCL/Gem
    2448
    1.14
    14.0
    KCL/Gem
    2448
    1.02
    1.0
    Other
    2448
    1.14
    1.0
    BRINE
    2470
    1.14
    16.0
    KCL/Gem
    2511
    1.02
    1.0
    Other
    2511
    1.13
    1.0
    BRINE
    2511
    1.15
    13.0
    KCL/Gem
    2600
    1.14
    16.0
    KCL/Gem