Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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22.07.2024 - 01:26
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7220/11-5 S

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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.
    7220/11-5 S
    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.
    PLUGGED
    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.
    7220/11-5
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    LN15M02. Inline 2220. crossline 2449
    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.
    1690-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.
    186
    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,
    06.04.2018
    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.
    08.10.2018
    Plugged date
    Date when plugging operations was finished, as reported by the operator to the Norwegian Offshore Directorate through DDRS (Daily Drilling Reporting System).
    08.10.2018
    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.
    08.10.2020
    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.
    08.10.2020
    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.
    CARBONIFEROUS
    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.
    FALK 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 PERMIAN
    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.
    ØRN FM
    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.
    386.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3057.0
    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).
    1937.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    90.1
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    72
    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.
    EARLY PERMIAN
    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.
    ØRN 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' 21.13'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    20° 29' 21.26'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    8000277.53
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    688872.81
    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.
    8381
  • Wellbore history

    General
    Well 7220/11-5 S was drilled to appraise the Alta oil and gas discovery on the Loppa High in the Barents Sea. The well was planned to drill horizontally through the Falk and Ørn formations oil leg in the Alta discovery. The objective was to demonstrate horizontal drillability through karstified and fractured carbonates using currently available technology. If successful, an extended test production was planned.
    Operations and results
    Appraisal well 7220/11-5 S was spudded with the semi-submersible installation Leiv Eiriksson on 6 April 2018. The well was drilled to TD in the 26” hole without significant problems. When installing BOP and riser the BOP suffered severe damage and 26.5 days were spent on repairs. After this drilling commenced without further significant issues. It was drilled vertical down to 1100 m, then building angle landing at 90° at 2375 m (1937 m TVD) in the oil leg in the Late Carboniferous Falk Formation. From this point it was drilled stratigraphically upwards from carbonates and heterolithics of the Falk Formation into younger carbonates of the Early Permian Ørn Formation. Well TD was set at 3057 m (1937 m TVD RKB) in the reef-type facies of the Ørn Formation. The well was drilled with seawater and hi-vis pills down to 478 m, with KCl/Polymer/GEM mud from 478 m to 794 m, with Performadril mud from 794 m to 2336 m, and with Baradril-N mud from 664 m to TD.
    Base Triassic/top Falk Formation gas-filled carbonates was encountered at 1911 m (1787 m TVD). The well penetrated a 117-metre TVD gas column in the Carboniferous Falk formation, and a 720-meter horizontal section was drilled in the Falk and Ørn formation. The horizontal section is situated 32 metres under the gas-oil contact at 2161 m (1905 m TVD), and 12 metres TVD over the regional oil-water contact. The reservoir consists of a mix of siliciclastic and carbonate rocks in the Falk formation and carbonate rocks in the Ørn formation from the Late Carboniferous to Early Permian period. The reservoir quality is good to very good.
    Above 1660 m numerous sandstone beds in the Snadd formation, varying in thickness from a meter to ca 20 m, had oil shows in the form of direct and cut fluorescence. Towards the top of the Snadd Formation the shows also included trace to 10% oil staining.
    No cores were cut. No fluid sample was taken on wireline, but extensive fluid sampling was conducted during the production test.
    After reaching final TD on 25 June 2018 the well bore was formally renamed as 7220/11-T-5 S for the long-term test. The well bore was permanently abandoned on 8 October 2018 as an oil and gas appraisal.
    Testing
    A successful long-term test of approximately two months duration was conducted beginning at 13 July 2018. The first main flow period of 30 days gave a controlled production rate of up to 1200 Sm3/day through a 60/64 inch choke. For the second main flow period of 35 days the rate was increased to up to 3000 Sm3/day through a 118/64 inch choke. The GOR during clean up and first flow period was 105 Sm3/Sm3, increasing to 165 Sm3/Sm3 at higher production rates in the second main flow. Two production logging runs (PLT) were performed during the production tests to measure the contribution from different reservoir zones. The production testing revealed good and very good reservoir properties and production rates without significant breakthrough of water or gas. About 110,000 Sm3 of liquid in total was produced during the test production. The temperature was measured by the downhole gauges during the extended well test. Based on these, the static formation temperature is estimated to be 72°C at 1927 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]
    480.00
    3056.00
  • Palynological slides at the Norwegian Offshore Directorate

    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    490.0
    [m]
    DC
    APT
    510.0
    [m]
    DC
    APT
    530.0
    [m]
    DC
    APT
    550.0
    [m]
    DC
    APT
    570.0
    [m]
    DC
    APT
    590.0
    [m]
    DC
    APT
  • 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
    31.07.2018 - 16:00
    YES
  • Lithostratigraphy

  • Logs

    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    IBC CBL GR
    494
    1667
    IBC CBL GR
    497
    1729
    MRM EZSV
    930
    1036
    MWD LWD - GR RES AC DENS NEU
    410
    3052
    PLT-FSI PCMS GR CCL MAXTRAC
    1805
    3036
    PLT-FSI RST PBMS MAXTRAC
    1800
    3050
  • 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
    477.5
    36
    478.0
    0.00
    SURF.COND.
    20
    787.4
    26
    794.0
    1.40
    FIT
    INTERM.
    10 3/4
    1847.6
    12 1/4
    1862.0
    1.40
    FIT
    LINER
    8 5/8
    2330.0
    9 1/2
    2336.0
    1.35
    FIT
    LINER
    5 1/2
    3051.0
    8 1/2
    3057.0
    0.00
  • Drilling mud

    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    411
    1.05
    18.0
    SWEEPS
    411
    1.00
    1.0
    Drill water
    424
    1.50
    20.0
    KCL/Gem Kill Mud
    450
    1.05
    18.0
    SWEEPS
    478
    1.05
    20.0
    SWEEPS
    478
    1.50
    17.0
    KCL/Gem Kill Mud
    479
    1.35
    16.0
    KCL/Polymer/GEM
    481
    1.34
    17.0
    KCL/Polymer/GEM
    497
    1.35
    17.0
    KCL/Polymer/GEM
    511
    1.36
    15.0
    KCL/Poly/GEM
    554
    1.39
    18.0
    KCL/Polymer/GEM
    621
    1.40
    19.0
    KCL/Polymer/GEM
    794
    1.39
    24.0
    KCL/Poly/GEM
    794
    1.22
    14.0
    Performadril
    794
    1.03
    10.0
    Sea Water
    794
    1.40
    22.0
    KCL/Poly/GEM
    1075
    1.22
    14.0
    KCL/Gem
    1075
    1.39
    15.0
    KCL/Gem
    1774
    1.39
    16.0
    KCL/Gem
    1774
    1.06
    0.1
    Riser completion fluid
    1774
    1.27
    0.1
    BRINE
    1783
    1.20
    19.0
    Performadril
    1813
    1.22
    18.0
    Performadril
    1847
    1.20
    19.0
    Performadril
    1847
    1.22
    18.0
    Performadril
    2048
    1.22
    17.0
    Performadril
    2105
    1.20
    19.0
    Performadril
    2260
    1.14
    19.0
    Baradril-N
    2289
    1.20
    19.0
    Performadril
    2330
    1.14
    19.0
    BARADRIL-N
    2330
    1.20
    17.0
    Performadril
    2340
    1.14
    11.0
    BARADRIL-N
    2646
    1.15
    12.0
    BARADRIL-N
    2756
    1.15
    12.0
    BARADRIL-N
    2794
    1.14
    11.0
    Performadril
    2794
    1.15
    11.0
    BARADRIL-N
    2810
    1.14
    13.0
    Performadril
    3057
    1.14
    10.0
    Baradril-N
    3057
    1.14
    18.0
    Baradril-N