Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
22.12.2024 - 01:25
Time of last synchronization with Norwegian Offshore Directorate's internal systems

7324/3-1

Export: PDF icon PDF

  • General information
    General information
    Attribute Value
    Wellbore name
    Official name of wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    7324/3-1
    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
    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
    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.
    7324/3-1
    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.
    1728-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.
    38
    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,
    15.10.2018
    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.
    21.11.2018
    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.
    01.07.2020
    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.
    21.11.2018
    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.
    01.07.2020
    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.
    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.
    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.
    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.
    SNADD 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.
    MIDDLE 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.
    SNADD FM
    3rd level with HC, age
    Age of lithostratigraphic unit, 3rd level, where hydrocarbons were encountered. Examples of legal values: CRETACEOUS, EARLY CRETACEOUS, LATE JURASSIC, EOCENE.
    MIDDLE JURASSIC
    3rd level with HC, formation
    Name of lithostartigraphic unit, 3rd 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.
    STØ FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    31.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    452.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    1709.0
    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).
    1709.0
    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.
    SNADD FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    73° 57' 27.39'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    24° 41' 4.86'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    8208923.97
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    428594.05
    UTM zone
    Universal Transverse Mercator zone. Examples of legal values: 31, 32, 33, 34.
    35
    NPDID wellbore
    Norwegian Offshore Directorate's unique id for the wellbore.
    8568

  • Wellbore history
    General
    Well 7324/3-1 was drilled to test the Intrepid Eagle structure on the Bjarmeland Platform, about 13 km west of the 7325/1-1 Atlantis discovery in the Barents Sea. The objective was to test the hydrocarbon potential and phase in channelized sandstones at two levels within the Snadd Formation. The Primary target was the Carnian age Intrepid Eagle Main channel. The secondary target was the deeper-seated Atlantis channel, also of Triassic age, and in which a gas down-to situation was found in well 7325/1-1 (Atlantis).
    Operations and results
    Wildcat well 7324/3-1 was spudded with the semi-submersible installation West Hercules on 15 October 2018 and drilled to 1709 m in the Late Triassic Snadd Formation. Operations proceeded without significant problems. The well was drilled with seawater and hi-vis pills down to 839 m and with KCl/polymer/GEM mud from 839 m to TD.
    A Stø Formation sand package was penetrated from 877 to 909 m and proved to be water bearing as expected. The primary target Intrepid Eagle Main channel sand of Carnian age was encountered at 1493 m. It was gas bearing with gas-water contact was at 1518.4 m. The secondary target Atlantis channel was encountered at 1642 m. It was gas-bearing down to a gas-water contact at 1666 m. The Atlantis channel is dated to the Middle Triassic (Ladinian). The reservoir quality in primary and secondary targets is moderate. The porosity is generally good (22% in average in Intrepid-Eagle Main, 17% in average in Atlantis). However, the permeability is limited (around 100 mD in the best parts of Intrepid-Eagle Main, 30-40 mD in the best parts of Atlantis).
    Oil shows in the form of fluorescence and cut were recorded almost throughout the well below ca 855 m in the Fuglen Formation. The shows were however rated poor and inconclusive, and much of the fluorescence could be from minerals. The strongest show outside of the gas-bearing intervals was at 1530 m in the Intrepid Eagle Main sandstone where also a weak petroleum odour and stain was recorded.
    A 60.68 m conventional core was cut in the Carn02 member with 99.5% recovery. A second 51.35m conventional core was cut in the Atlantis discovery level (secondary target) with 100% recovery. MDT fluid samples were taken at 1505.2 m (gas), 1512.2 m (gas), 1532.8 m (water), 1645.2 m (gas), and 1675.1 m (water) .
    The well was permanently abandoned on 21 November 2018 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]
    843.00
    1656.00

  • 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
    1507.0
    1567.7
    [m ]
    2
    1658.0
    1709.4
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    112.0
    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
    36
    533.0
    42
    535.0
    0.00
    INTERM.
    13 3/8
    833.0
    17 1/2
    839.0
    0.00
    LINER
    9 5/8
    1224.0
    12 1/4
    1425.0
    0.00
    OPEN HOLE
    1709.0
    8 1/2
    1709.0
    0.00

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CMR MDT
    1475
    1706
    FMI MSIP
    1383
    1705
    HRLA PEX ECS
    1425
    1709
    MDT PA
    1512
    1645
    MSIP ECS HRLA PEX
    476
    1424
    MWD LWD - ARC TELE
    532
    839
    MWD LWD - GVR ARC TELE
    839
    1658
    ZO VSP
    452
    1628

  • Lithostratigraphy

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    842
    1.14
    14.0
    KCl/Polymer/GEM
    1324
    1.17
    11.0
    KCl/Polymer/GEM
    1324
    1.16
    12.0
    KCl/Polymer/GEM
    1365
    1.14
    15.0
    KCl/Polymer/GEM
    1451
    1.17
    12.0
    KCl/Polymer/GEM
    1497
    1.14
    13.0
    KCl/Polymer/GEM
    1507
    1.16
    14.0
    KCl/Polymer/GEM
    1708
    1.16
    12.0
    KCl/Polymer/GEM

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    843.0
    [m]
    DC
    CGG
    849.0
    [m]
    DC
    CGG
    855.0
    [m]
    DC
    CGG
    861.0
    [m]
    DC
    CGG
    867.0
    [m]
    DC
    CGG
    873.0
    [m]
    DC
    CGG
    879.0
    [m]
    DC
    CGG
    885.0
    [m]
    DC
    CGG
    891.0
    [m]
    DC
    CGG
    894.0
    [m]
    DC
    CGG
    898.5
    [m]
    C
    CGG
    903.0
    [m]
    DC
    CGG
    909.0
    [m]
    DC
    CGG
    915.0
    [m]
    DC
    CGG
    921.0
    [m]
    DC
    CGG
    927.0
    [m]
    DC
    CGG
    933.0
    [m]
    DC
    CGG
    939.0
    [m]
    DC
    CGG
    945.0
    [m]
    DC
    CGG
    995.0
    [m]
    DC
    CGG
    1010.0
    [m]
    DC
    CGG
    1025.0
    [m]
    DC
    CGG
    1040.0
    [m]
    DC
    CGG
    1055.0
    [m]
    DC
    CGG
    1070.0
    [m]
    DC
    CGG
    1085.0
    [m]
    DC
    CGG
    1100.0
    [m]
    DC
    CGG
    1115.0
    [m]
    DC
    CGG
    1130.0
    [m]
    DC
    CGG
    1145.0
    [m]
    DC
    CGG
    1160.0
    [m]
    DC
    CGG
    1175.0
    [m]
    DC
    CGG
    1190.0
    [m]
    DC
    CGG
    1205.0
    [m]
    DC
    CGG
    1220.0
    [m]
    DC
    CGG
    1235.0
    [m]
    DC
    CGG
    1250.0
    [m]
    DC
    CGG
    1265.0
    [m]
    DC
    CGG
    1280.0
    [m]
    DC
    CGG
    1295.0
    [m]
    DC
    CGG
    1310.0
    [m]
    DC
    CGG
    1325.0
    [m]
    DC
    CGG
    1340.0
    [m]
    DC
    CGG
    1355.0
    [m]
    DC
    CGG
    1370.0
    [m]
    DC
    CGG
    1385.0
    [m]
    DC
    CGG
    1400.0
    [m]
    DC
    CGG
    1415.0
    [m]
    DC
    CGG
    1428.0
    [m]
    DC
    CGG
    1434.0
    [m]
    DC
    CGG
    1440.0
    [m]
    DC
    CGG
    1446.0
    [m]
    DC
    CGG
    1452.0
    [m]
    DC
    CGG
    1456.0
    [m]
    DC
    CGG
    1464.0
    [m]
    DC
    CGG
    1470.0
    [m]
    DC
    CGG
    1476.0
    [m]
    DC
    CGG
    1482.0
    [m]
    DC
    CGG
    1488.0
    [m]
    DC
    CGG
    1494.0
    [m]
    DC
    CGG
    1500.0
    [m]
    DC
    CGG
    1506.0
    [m]
    DC
    CGG
    1531.9
    [m]
    C
    CGG
    1536.5
    [m]
    C
    CGG
    1539.8
    [m]
    C
    CGG
    1544.8
    [m]
    C
    CGG
    1549.6
    [m]
    C
    CGG
    1553.9
    [m]
    C
    CGG
    1557.5
    [m]
    C
    CGG
    1561.5
    [m]
    C
    CGG
    1566.6
    [m]
    C
    CGG
    1567.4
    [m]
    C
    CGG
    1572.0
    [m]
    DC
    CGG
    1578.0
    [m]
    DC
    CGG
    1584.0
    [m]
    DC
    CGG
    1590.0
    [m]
    DC
    CGG
    1596.0
    [m]
    DC
    CGG
    1602.0
    [m]
    DC
    CGG
    1608.0
    [m]
    DC
    CGG
    1614.0
    [m]
    DC
    CGG
    1620.0
    [m]
    DC
    CGG
    1626.0
    [m]
    DC
    CGG
    1632.0
    [m]
    DC
    CGG
    1638.0
    [m]
    DC
    CGG
    1644.0
    [m]
    DC
    CGG
    1650.0
    [m]
    DC
    CGG
    1656.0
    [m]
    DC
    CGG
    1663.8
    [m]
    C
    CGG
    1668.7
    [m]
    C
    CGG
    1679.1
    [m]
    C
    CGG
    1684.7
    [m]
    C
    CGG
    1686.9
    [m]
    C
    CGG
    1691.8
    [m]
    C
    CGG
    1696.5
    [m]
    C
    CGG
    1700.7
    [m]
    C
    CGG
    1704.7
    [m]
    C
    CGG
    1708.9
    [m]
    C
    CGG
    1782.0
    [m]
    DC
    CGG