Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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sodir.no          Norsk
22.12.2024 - 01:25
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7220/2-1

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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.
    7220/2-1
    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).
    WILDCAT
    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.
    7220/2-1
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    WG0901:inline1591 & xline 9391
    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.
    Statoil Petroleum 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.
    1543-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.
    14
    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,
    26.09.2014
    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.
    10.10.2014
    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.
    10.10.2016
    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.
    12.10.2016
    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.
    WILDCAT
    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.
    YES
    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.
    MIDDLE JURASSIC
    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.
    STØ 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 JURASSIC
    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.
    NORDMELA FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    40.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    429.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    1594.0
    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).
    1590.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    9.6
    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.
    LATE TRIASSIC
    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.
    SNADD FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    72° 48' 43.85'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    20° 33' 26.97'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    8088240.43
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    683076.25
    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.
    7558

  • Wellbore history
    General
    Well 7220/2-1 was drilled to test the Isfjell prospect in the Bjørnøyrenna Fault Complex between the Bjørnøya Basin and the Loppa High in the western Barents Sea. The main purpose of the well was to test the hydrocarbon potential and phase in the Stø, Nordmela and Tubåen formations of Early - Middle Jurassic age. The Snadd Formation was a secondary target.
    Operations and results
    Wildcat well 7220/2-1 was spudded with the semi-submersible installation Transocean Spitsbergen on 26 August 2014. After drilling the 36" section down to 501 m the well was set on hold while drilling a separate 9 7/8" pilot hole (7220/2-U-2) from seabed to 678 m to look for shallow gas. No shallow gas was seen. After this, on 28 August, the rig was moved to drill the 7125/4-3 Ensis well. On 22 September, the rig returned to location and drilling of the main well commenced to TD at 1594 m in the Late Triassic Snadd Formation. No significant problem was encountered in the operations. The well was drilled with seawater down to 678 m and with KCl/Polymer/Glycol from 678 m to TD.
    The well penetrated Quaternary and Tertiary claystones as well as Jurassic and Triassic sandstones, claystones and siltstones. Top Stø Formation was penetrated at 828 m. Gas was present in Stø and Nordmela formations with a possible GOC at 912 m and a thin (2 m) oil leg. The oil was indicated from resistivity, hydrocarbon core scanner and core extracts. Below the oil, there were good shows down to 922 m. Organic geochemical analyses proved the gas to be thermogenic in origin with no sign of biodegradation. No hydrocarbon indications were observed in the Snadd Formation.
    Three cores were cut. Core 1 was cut from 800 to 827 m in the overburden Kolmule shale for rock mechanical purposes. Cores 2 and 3 were cut from 834 to 936.5 m in the reservoir section. MDT gas samples were taken at 886.6 m, while water samples were taken at 983 m.
    The well was permanently abandoned on 10 October 2014 as a gas discovery.
    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]
    680.00
    1594.00

  • 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
    800.0
    826.6
    [m ]
    2
    834.0
    889.1
    [m ]
    3
    889.1
    933.5
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    126.1
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    680.0
    [m]
    DC
    ROBERTSO
    690.0
    [m]
    DC
    ROBERT
    700.0
    [m]
    DC
    ROBERT
    710.0
    [m]
    DC
    ROBERT
    720.0
    [m]
    DC
    ROBERT
    730.0
    [m]
    DC
    ROBERT
    740.0
    [m]
    DC
    ROBERT
    750.0
    [m]
    DC
    ROBERT
    760.0
    [m]
    DC
    ROBERT
    770.0
    [m]
    DC
    ROBERT
    779.0
    [m]
    DC
    ROBERT
    782.0
    [m]
    DC
    ROBERT
    788.0
    [m]
    DC
    ROBERT
    794.0
    [m]
    DC
    ROBERT
    800.2
    [m]
    C
    ROBERT
    804.5
    [m]
    C
    ROBERT
    808.4
    [m]
    C
    ROBERT
    811.6
    [m]
    C
    ROBERT
    814.6
    [m]
    C
    ROBERT
    821.3
    [m]
    C
    ROBERT
    823.5
    [m]
    C
    ROBERT
    824.3
    [m]
    C
    ROBERT
    825.5
    [m]
    C
    ROBERT
    826.3
    [m]
    C
    ROBERT
    834.4
    [m]
    C
    ROBERT
    838.9
    [m]
    C
    ROBERT
    842.9
    [m]
    C
    ROBERT
    847.5
    [m]
    C
    ROBERT
    851.9
    [m]
    C
    ROBERT
    856.3
    [m]
    C
    ROBERT
    861.9
    [m]
    C
    ROBERT
    868.0
    [m]
    C
    ROBERT
    875.8
    [m]
    C
    ROBERT
    877.7
    [m]
    C
    ROBERT
    883.5
    [m]
    C
    ROBERT
    888.4
    [m]
    C
    ROBERT
    890.4
    [m]
    C
    ROBERT
    894.6
    [m]
    C
    ROBERT
    899.3
    [m]
    C
    ROBERT
    901.7
    [m]
    C
    ROBERT
    908.5
    [m]
    C
    ROBERT
    914.3
    [m]
    C
    ROBERT
    919.4
    [m]
    C
    ROBERT
    923.8
    [m]
    C
    ROBERT
    927.8
    [m]
    C
    ROBERT
    932.3
    [m]
    C
    ROBERT
    940.0
    [m]
    DC
    ROBERT
    945.0
    [m]
    DC
    ROBERT
    950.0
    [m]
    DC
    ROBERT
    955.0
    [m]
    DC
    ROBERT
    960.0
    [m]
    DC
    ROBERT
    965.0
    [m]
    DC
    ROBERT
    970.0
    [m]
    DC
    ROBERT
    975.0
    [m]
    DC
    ROBERT
    980.0
    [m]
    DC
    ROBERT
    985.0
    [m]
    DC
    ROBERT
    990.0
    [m]
    DC
    ROBERT
    995.0
    [m]
    DC
    ROBERT
    1000.0
    [m]
    DC
    ROBERT
    1010.0
    [m]
    DC
    ROBERT
    1015.0
    [m]
    DC
    ROBERT
    1020.0
    [m]
    DC
    ROBERT
    1030.0
    [m]
    DC
    ROBERT
    1035.0
    [m]
    DC
    ROBERT
    1040.0
    [m]
    DC
    ROBERT
    1050.0
    [m]
    DC
    ROBERT
    1055.0
    [m]
    DC
    ROBERT
    1060.0
    [m]
    DC
    ROBERT
    1070.0
    [m]
    DC
    ROBERT
    1075.0
    [m]
    DC
    ROBERT
    1080.0
    [m]
    DC
    ROBERT
    1090.0
    [m]
    DC
    ROBERT
    1095.0
    [m]
    DC
    ROBERT
    1100.0
    [m]
    DC
    ROBERT
    1110.0
    [m]
    DC
    ROBERT
    1115.0
    [m]
    DC
    ROBERT
    1120.0
    [m]
    DC
    ROBERT
    1125.0
    [m]
    DC
    ROBERT
    1130.0
    [m]
    DC
    ROBERT
    1140.0
    [m]
    DC
    ROBERT
    1160.0
    [m]
    DC
    ROBERT
    1170.0
    [m]
    DC
    ROBERT
    1190.0
    [m]
    DC
    ROBERT
    1200.0
    [m]
    DC
    ROBERT
    1220.0
    [m]
    DC
    ROBERT
    1230.0
    [m]
    DC
    ROBERT
    1250.0
    [m]
    DC
    ROBERT
    1260.0
    [m]
    DC
    ROBERT
    1280.0
    [m]
    DC
    ROBERT
    1290.0
    [m]
    DC
    ROBERT
    1310.0
    [m]
    DC
    ROBERT
    1320.0
    [m]
    DC
    ROBERT
    1340.0
    [m]
    DC
    ROBERT
    1350.0
    [m]
    DC
    ROBERT
    1370.0
    [m]
    DC
    ROBERT
    1380.0
    [m]
    DC
    ROBERT
    1400.0
    [m]
    DC
    ROBERT
    1410.0
    [m]
    DC
    ROBERT
    1430.0
    [m]
    DC
    ROBERT
    1440.0
    [m]
    DC
    ROBERT
    1460.0
    [m]
    DC
    ROBERT
    1470.0
    [m]
    DC
    ROBERT
    1490.0
    [m]
    DC
    ROBERT
    1500.0
    [m]
    DC
    ROBERT
    1520.0
    [m]
    DC
    ROBERT
    1530.0
    [m]
    DC
    ROBERT
    1550.0
    [m]
    DC
    ROBERT
    1565.0
    [m]
    DC
    ROBERT
    1579.0
    [m]
    DC
    ROBERT
    1594.0
    [m]
    DC
    ROBERT

  • Lithostratigraphy

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    MDT
    828
    1559
    MWD - ARC6 TELE675
    678
    773
    MWD - PERI15
    773
    1594
    MWD- TELE ARCVRES9
    510
    640
    PEX HRLA MSIP
    767
    1591
    VSI4
    422
    1520

  • 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
    517.0
    36
    520.2
    0.00
    INTERM.
    13 3/8
    670.7
    17 1/2
    678.5
    1.19
    FIT
    INTERM.
    9 5/8
    767.2
    12 1/4
    773.5
    1.45
    FIT
    OPEN HOLE
    1594.0
    8 1/2
    1594.0
    0.00

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    529
    1.20
    52.0
    Low Sulphate/KCl/Polymer/Glycol
    678
    1.14
    18.0
    Low Sulphate/KCl/Polymer/Glycol
    678
    1.14
    27.0
    KCl/Polymer/GEM
    740
    1.14
    19.0
    KCl/Polymer/Glycol
    800
    1.17
    19.0
    Low Sulphate/KCl/Polymer/Glycol
    935
    1.17
    30.0
    Low Sulphate/KCl/Polymer/Glycol
    1202
    1.16
    49.0
    Low Sulphate/KCl/Polymer/Glycol
    1594
    1.16
    58.0
    Low Sulphate/KCl/Polymer/Glycol