Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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22.12.2024 - 01:25
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7219/9-3

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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.
    7219/9-3
    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
    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
    Well name
    Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    7219/9-3
    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.
    Equinor Energy 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.
    1802-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.
    18
    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,
    12.07.2020
    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.
    29.07.2020
    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.
    29.07.2022
    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.
    29.07.2020
    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.
    08.08.2022
    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
    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.
    DRY
    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
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    32.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    326.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    1338.0
    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).
    1338.0
    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.
    FRUHOLMEN FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    72° 17' 22.98'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    19° 59' 56.48'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    8028519.68
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    669568.04
    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.
    8960

  • Wellbore history
    General
    Well 7219/9-3 was drilled to test the Mist prospect on the border between the Bjørnøyrenna Fault Complex and the Polhem Sub-platform in the Barents Sea. The primary objective was to prove hydrocarbon contacts and commercial oil volumes in the Early Jurassic Tubåen Formation. Secondary objective was to  collect data to improve understanding of potential reservoir rocks in the Late Triassic Fruholmen Formation.
    Operations and results
    A 9 7/8" pilot hole (7219/9-U-1) was spudded 20-25 m away from the main bore location on the 9 July 2020 and drilled down to the planned TD of the 17 ½’’ section at 757 m to check for shallow gas and reduce the depth uncertainty towards a seismic anomaly. No shallow gas was observed during drilling and the geological uncertainty was reduced by using seismic while drilling.
    Wildcat well 7219/9-3 was spudded with the semi-submersible installation Transocean Enabler on 12 July 2020 and drilled to TD at 1338 m in the Late Triassic Fruholmen Formation. Operations proceeded without significant problems. The well was drilled with seawater and hi-vis pills down to 757 m and with BaraHIB water-based mud from 757 m to TD.
    In the primary exploration target, the well encountered the Tubåen Formation with a thickness of 131 metres, of which 50 metres was sandstone layers with very good reservoir properties. Two hundred and sixty-nine metres of the Fruholmen Formation were drilled in the secondary exploration target, whereof several sandstone layers totalling 75 metres with reservoir properties varying from good to very good. The Tubåen and Fruholmen formations were water bearing with low gas readings and no hydrocarbon indications. The only hydrocarbon indications in the well were shows on cuttings and sidewall cores in the Paleocene Torsk Formation: Faint petroleum odour, direct and cut fluorescence were described in siltstones in the interval 811 to 825 m, and in a sandstone sidewall core at 920.5 m.
    No conventional cores were cut. MDT water samples were taken at 1052 m.
    The well was permanently abandoned on 29 July 2020 as a dry well.
    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]
    760.00
    1338.00

  • 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
    407.7
    36
    409.0
    0.00
    SURF.COND.
    13 3/8
    750.7
    17 1/2
    757.0
    1.27
    FIT
    INTERM.
    9 5/8
    889.5
    12 1/4
    895.0
    1.32
    FIT
    OPEN HOLE
    1338.0
    8 1/2
    1338.0
    0.00

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CMR MDT
    889
    1338
    HRLA PEX
    751
    892
    MWD - DIR
    358
    409
    MWD - GR RES APWD DIR
    895
    1338
    MWD - GR RES DIR APWD
    409
    757
    MWD - GR RES SON SWD DIR APWD
    757
    895
    VSP GR
    560
    1331
    XLR GR
    762
    886
    XLR GR
    907
    1298
    XPT MSIP HRLA PEX
    889
    1338

  • Lithostratigraphy
    Lithostratigraphy
    Top depth [mMD RKB]
    Lithostrat. unit
    358
    358
    466
    466
    938
    938
    1069

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    763.0
    [m]
    DC
    CGG
    772.0
    [m]
    DC
    CGG
    781.0
    [m]
    DC
    CGG
    790.0
    [m]
    DC
    CGG
    799.0
    [m]
    DC
    CGG
    808.0
    [m]
    DC
    CGG
    817.0
    [m]
    DC
    CGG
    826.0
    [m]
    DC
    CGG
    835.0
    [m]
    DC
    CGG
    844.0
    [m]
    DC
    CGG
    853.0
    [m]
    DC
    CGG
    862.0
    [m]
    DC
    CGG
    871.0
    [m]
    DC
    CGG
    880.0
    [m]
    DC
    CGG
    889.0
    [m]
    DC
    CGG
    907.0
    [m]
    DC
    CGG
    907.0
    [m]
    SWC
    CGG
    916.0
    [m]
    DC
    CGG
    922.0
    [m]
    DC
    CGG
    928.0
    [m]
    DC
    CGG
    934.0
    [m]
    DC
    CGG
    940.0
    [m]
    DC
    CGG
    940.0
    [m]
    SWC
    CGG
    946.0
    [m]
    DC
    CGG
    952.0
    [m]
    DC
    CGG
    958.0
    [m]
    DC
    CGG
    964.0
    [m]
    DC
    CGG
    970.0
    [m]
    DC
    CGG
    976.0
    [m]
    DC
    CGG
    982.0
    [m]
    DC
    CGG
    988.0
    [m]
    DC
    CGG
    994.0
    [m]
    DC
    CGG
    1000.0
    [m]
    DC
    CGG
    1006.0
    [m]
    DC
    CGG
    1012.0
    [m]
    DC
    CGG
    1018.0
    [m]
    DC
    CGG
    1024.0
    [m]
    DC
    CGG
    1030.0
    [m]
    DC
    CGG
    1036.0
    [m]
    DC
    CGG
    1042.0
    [m]
    DC
    CGG
    1048.0
    [m]
    DC
    CGG
    1049.0
    [m]
    SWC
    CGG
    1054.0
    [m]
    DC
    CGG
    1060.0
    [m]
    DC
    CGG
    1066.0
    [m]
    DC
    CGG
    1070.0
    [m]
    SWC
    CGG
    1072.0
    [m]
    DC
    CGG
    1078.0
    [m]
    DC
    CGG
    1084.0
    [m]
    DC
    CGG
    1085.0
    [m]
    SWC
    CGG
    1090.0
    [m]
    DC
    CGG
    1096.0
    [m]
    DC
    CGG
    1102.0
    [m]
    DC
    CGG
    1108.0
    [m]
    DC
    CGG
    1114.0
    [m]
    DC
    CGG
    1120.0
    [m]
    DC
    CGG
    1126.0
    [m]
    DC
    CGG
    1132.0
    [m]
    DC
    CGG
    1138.0
    [m]
    DC
    CGG
    1144.0
    [m]
    DC
    CGG
    1150.0
    [m]
    DC
    CGG
    1156.0
    [m]
    DC
    CGG
    1162.0
    [m]
    DC
    CGG
    1168.0
    [m]
    DC
    CGG
    1173.2
    [m]
    SWC
    CGG
    1174.0
    [m]
    DC
    CGG
    1180.0
    [m]
    DC
    CGG
    1186.0
    [m]
    DC
    CGG
    1192.0
    [m]
    DC
    CGG
    1198.0
    [m]
    DC
    CGG
    1204.0
    [m]
    DC
    CGG
    1210.0
    [m]
    DC
    CGG
    1216.0
    [m]
    DC
    CGG
    1222.0
    [m]
    DC
    CGG
    1228.0
    [m]
    DC
    CGG
    1234.0
    [m]
    DC
    CGG
    1240.0
    [m]
    DC
    CGG
    1245.0
    [m]
    SWC
    CGG
    1246.0
    [m]
    DC
    CGG
    1252.0
    [m]
    DC
    CGG
    1258.0
    [m]
    DC
    CGG
    1264.0
    [m]
    DC
    CGG
    1270.0
    [m]
    DC
    CGG
    1276.0
    [m]
    DC
    CGG
    1282.0
    [m]
    DC
    CGG
    1282.5
    [m]
    DC
    CGG
    1288.0
    [m]
    DC
    CGG
    1294.0
    [m]
    DC
    CGG
    1300.0
    [m]
    DC
    CGG
    1306.0
    [m]
    DC
    CGG
    1312.0
    [m]
    DC
    CGG
    1318.0
    [m]
    DC
    CGG
    1324.0
    [m]
    DC
    CGG
    1330.0
    [m]
    DC
    CGG
    1338.6
    [m]
    SWC
    CGG