Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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25.11.2024 - 01:30
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7220/11-4

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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.
    7220/11-4
    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
    Multilateral
    Indicator telling if the parent well is multilateral, meaning it has more than one branch radiating from the main borehole. Example of legal values: YES, NO. See also Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    NO
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    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.
    7220/11-4
    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.
    1653-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.
    69
    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,
    10.05.2017
    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.
    17.07.2017
    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.
    17.07.2019
    Plugged date
    Date when plugging operations was finished, as reported by the operator to the Norwegian Offshore Directorate through DDRS (Daily Drilling Reporting System).
    17.07.2017
    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.
    17.07.2019
    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
    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 PERMIAN
    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.
    UNDEFINED GP
    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.
    UNDEFINED GP
    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.
    401.7
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2282.0
    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).
    2280.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    9.33
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    84
    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° 2' 27.88'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    20° 33' 7.97'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    8002536.65
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    690843.65
    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.
    8126

  • Wellbore history
    General
    Well 7220/11-4 was drilled to appraise the Alta discovery on the southern Loppa High in the Barents Sea. The primary objective was to delineate the eastern extent of the Alta discovery and prove the presence of hydrocarbon columns and fluid contacts similar to those established in the discovery well.
    Operations and results
    Appraisal well 7220/11-4 was spudded with the semi-submersible installation Leiv Eiriksson on 10 May 2017 and drilled to TD at 2282 m in the Carboniferous Ugle Formation. Operations proceeded without significant problems. The well was drilled with seawater and sweeps down to 471 m, with KCl/Polymer/GEM mud from 471 to 648 m and with Performadril mud with 3.0 – 3.6% glycol from 648 m to TD.
    The top of the reservoir was encountered at 1903 m. The well encountered a gross hydrocarbon column of 46.3 m, comprising 1.6 m of gas and 44.7 m of oil in a sequence of Permian-Triassic clastic carbonate sediments, conglomerates and breccias. The gas-oil contact (GOC) was found at 1904.6 m and the free-water level (FWL) at 1949.3 m . The pressure data confirmed similar fluid contacts and gradients to those observed in the previous wells drilled on the Alta discovery, suggesting good communication across the large Alta structure.
    Above the oil-bearing reservoir there were oil shows in the Snadd Formation at 620 m, 860 – 930 m, and 1080 – 1288 m. These were described with direct, cut and residue fluorescence. The strongest shows, at 620 m, were associated with high gas levels between 600 and 650 m. Below the oil reservoir oil shows were described down to 2061 m.
    Seven cores were cut in the interval 1904 to 1994 m. Cores 1 – 5 were cut in the 8 ½" section, while cores 6 and 7 were cut in the 6" section. MDT fluid samples were taken in the 8 ½" section at 1903.2 m (gas), 1912.6 m (oil), 1920.52 m (oil), and 1934.71 m (oil). One XPT water sample was taken in the 6"section at 1988.49.
    The well was permanently abandoned on 17 July 2017 as an oil and gas appraisal.
    Testing
    A DST was performed in the oil zone, the perforated interval was from 1923 to 1936.3 m in the oil zone. In the main flow the test produced 960 sm3 oil and 93800 Sm3 gas /day through a 56/64" choke. The GOR was 97 Sm3/Sm3, the oil density was 0.825 g/cm3 and the gas gravity was 0.706 (air = 1). Measured CO2 and H2S was up to 3% and 1.4 ppm, respectively. The static formation temperature estimated from Metrol Prolog test data is 71 °C at 1939.3 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]
    500.00
    2282.00

  • 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
    1904.0
    1914.7
    [m ]
    2
    1915.7
    1934.0
    [m ]
    3
    1934.0
    1941.8
    [m ]
    4
    1942.0
    1960.2
    [m ]
    5
    1960.2
    1970.4
    [m ]
    6
    1972.6
    1990.8
    [m ]
    7
    1990.6
    1991.8
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    84.7
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • 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
    493.0
    36
    493.0
    0.00
    SURF.COND.
    20
    657.4
    26
    664.0
    1.30
    FIT
    INTERM.
    9 5/8
    1823.8
    12 1/4
    1830.0
    1.62
    LOT
    LINER
    7
    1968.6
    8 1/2
    1977.4
    1.35
    FIT
    OPEN HOLE
    2282.0
    6
    2282.0
    0.00

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    1923
    1936
    22.2
    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
    960
    93800
    0.825
    0.706
    97

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    ADT HRLA GR JAR
    1823
    1969
    FMI PPC MSIP GR JAR
    425
    1970
    FMI PPC MSIP GR JAR
    1968
    2264
    MSCT GR
    1836
    1903
    MSCT GR
    1976
    2118
    MSCT GR
    1983
    2246
    MWD - OTII BCPM
    427
    669
    MWD - OTII LT BCPMII
    2149
    2282
    MWD - OTII ST LT BCPMII
    1994
    2149
    MWD - ZT RG OT BCPMII
    1830
    1904
    MWD - ZT RG OT BCPMII
    1970
    1970
    MWD - ZT RG OTII BCPM LT ST
    669
    1830
    NEXT XMR GR JAR
    1823
    1961
    PQ HY PO SRP IFA MS PC JAR
    1988
    2101
    PQ HY PO SRP PQ IFA MS PC JAR
    1902
    1968
    UBI ADT HRLA PEX HNGS GR JAR
    1968
    2254
    UBI PEX GPIT PPC GR JAR
    1823
    1959
    UIB GPIT PPC GR JAR
    1967
    2265
    USIT CBL
    1250
    1964
    VSI GR
    436
    2260
    VSI GR
    457
    1965
    XPT NEXT CMR GR JAR
    1968
    2251

  • Lithostratigraphy

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    426
    1.05
    45.0
    SWEEPS
    453
    1.50
    22.0
    KCL/Gem
    471
    1.05
    45.0
    SWEEPS
    493
    1.50
    22.0
    KCl/Polymer/GEM
    493
    1.35
    15.0
    KCl/Polymer/GEM
    620
    1.17
    9.0
    KCl/Gem/Polymer
    620
    1.36
    17.0
    KCl/Polymer/GEM
    648
    1.39
    19.0
    KCl/Polymer/GEM
    658
    1.17
    19.0
    PerformaDril
    664
    1.17
    19.0
    Performadril
    664
    1.39
    19.0
    KCl/Polymer/GEM
    669
    1.17
    19.0
    Performadril
    860
    1.18
    19.0
    Performadril
    1018
    1.17
    19.0
    Performadril
    1100
    1.18
    19.0
    Performadril
    1270
    1.20
    19.0
    Performadril
    1350
    1.18
    19.0
    Performadril
    1452
    1.17
    9.0
    KCl/Gem/Polymer
    1452
    1.14
    10.0
    KCl/Gem/Polymer
    1475
    1.20
    19.0
    Performadril
    1570
    1.21
    20.0
    Performadril
    1788
    1.14
    10.0
    KCl/Gem/Polymer
    1794
    1.20
    19.0
    Performadril
    1830
    1.14
    20.0
    Performadril
    1830
    1.20
    19.0
    Performadril
    1835
    1.14
    21.0
    Performadril
    2282
    1.14
    11.0
    KCl/Gem/Polymer
    2282
    1.13
    1.0
    KCl