Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
09.05.2024 - 01:35
Time of last synchronization with Norwegian Offshore Directorate's internal systems

7324/6-1

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.
    7324/6-1
    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.
    7324/6-1
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    HCF Inline: 4609 Xline: 14315
    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.
    1761-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.
    24
    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,
    18.06.2019
    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.
    31.07.2019
    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.
    31.07.2019
    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.
    04.12.2020
    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.
    30.04.2021
    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.
    OIL
    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
    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.
    449.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    1600.0
    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).
    1600.0
    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° 39' 7.06'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    24° 58' 35.17'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    8174514.28
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    436432.08
    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.
    8741

  • Wellbore history
    General
    Well 7324/6-1 was drilled to test the Sputnik prospect in the Hoop Fault Complex on the Bjarmeland Platform in the Barents Sea. The prospect had several prospective targets found hydrocarbon-bearing in neighbouring wells. The primary objective was to test the hydrocarbon potential and phase in the Late Carnian interval in the Snadd Formation of Middle to Late Triassic age, called Carn03. Secondary objectives of the well were to clarify whether there was an oil leg present below the depth of the gas-water contact encountered in Well 7325/4-1 (Stø Formation), as well as testing two secondary targets in the Early to Middle Carnian interval of the Snadd formation (Carn02 & Carn01).
    Operations and results
    The well was entered with the semi-submersible drilling rig West Hercules on 18 June 2019 and drilled vertically to TD at 1600 m (1599.5 m TVD) in the Late Triassic Snadd Formation. The well was drilled down to 746 m with sea water and hi-vis sweeps and from 746 m to TD with Exploradrill oil-based mud.
    The Stø Formation was penetrated at 792 m and was found to be water bearing with good oil shows. The formation consists of a homogenous sandstone body. The top of Snadd Formation was encountered at 854 m and is continuously interbedded with claystone, siltstone, and sandstone intervals of varying thickness from submeter to more than ten meters in vertical scale. Carbonaceous material, especially in the sandstone was locally observed. The main targeted Carn03 was penetrated at 1061.5 m and consists of sandstone, interbedded with several thinner claystone beds. Fifty-eight meters of water bearing reservoir sandstone with oil shows was encountered with poor reservoir quality in Carn03. The secondary target, Carn02, was penetrated at 1368 m and consists of sandstone with two-meter scale limestone stringer close to top. A total oil column of 17 m was with an oil-water contact at 1385 m was encountered in the Carn02 reservoir of poor to moderate quality. The secondary target, Carn01, was penetrated at 1508 m and consists of two thick sandstone intervals at top and base, split by a siltstone and claystone interval in the middle. The Carn01 was found to be water bearing with a gross thickness of 41 m. The reservoir can be divided into two zones of predominantly sandstone. A 27 m core was cut in the Stø Formation, and a 63 m core was cut in Carn03 with good coverage and recovery. A 54 m core was cut in Carn02 with moderate reservoir coverage. No core was cut in the Carn01 interval. MDT fluid samples were taken at 1103.5 m (water), 1088 m (water), and 1378 m (oil and formation water)
    The well was permanently plugged and abandoned on 31 July 2019 as an oil discovery 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]
    749.00
    1600.00

  • 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
    795.0
    821.6
    [m ]
    2
    1070.0
    1132.4
    [m ]
    3
    1381.0
    1435.0
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    143.0
    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
    749.0
    [m]
    DC
    CGG
    755.0
    [m]
    DC
    CGG
    761.0
    [m]
    DC
    CGG
    767.0
    [m]
    DC
    CGG
    773.0
    [m]
    DC
    CGG
    779.0
    [m]
    DC
    CGG
    785.0
    [m]
    DC
    CGG
    791.0
    [m]
    DC
    CGG
    795.0
    [m]
    DC
    CGG
    795.6
    [m]
    C
    CGG
    798.9
    [m]
    C
    CGG
    810.3
    [m]
    C
    CGG
    811.5
    [m]
    C
    CGG
    814.6
    [m]
    C
    CGG
    817.7
    [m]
    C
    CGG
    820.5
    [m]
    C
    CGG
    821.3
    [m]
    C
    CGG
    824.0
    [m]
    DC
    CGG
    830.0
    [m]
    DC
    CGG
    836.0
    [m]
    DC
    CGG
    842.0
    [m]
    DC
    CGG
    847.0
    [m]
    DC
    CGG
    857.0
    [m]
    DC
    CGG
    867.0
    [m]
    DC
    CGG
    877.0
    [m]
    DC
    CGG
    887.0
    [m]
    DC
    CGG
    897.0
    [m]
    DC
    CGG
    907.0
    [m]
    DC
    CGG
    917.0
    [m]
    DC
    CGG
    927.0
    [m]
    DC
    CGG
    937.0
    [m]
    DC
    CGG
    957.0
    [m]
    DC
    CGG
    967.0
    [m]
    DC
    CGG
    976.0
    [m]
    DC
    CGG
    985.0
    [m]
    DC
    CGG
    994.0
    [m]
    DC
    CGG
    1003.0
    [m]
    DC
    CGG
    1012.0
    [m]
    DC
    CGG
    1039.0
    [m]
    DC
    CGG
    1048.0
    [m]
    DC
    CGG
    1066.0
    [m]
    DC
    CGG
    1073.4
    [m]
    C
    CGG
    1076.4
    [m]
    C
    CGG
    1078.9
    [m]
    C
    CGG
    1080.6
    [m]
    C
    CGG
    1083.5
    [m]
    C
    CGG
    1084.5
    [m]
    C
    CGG
    1087.9
    [m]
    C
    CGG
    1095.3
    [m]
    C
    CGG
    1103.3
    [m]
    C
    CGG
    1108.8
    [m]
    C
    CGG
    1111.3
    [m]
    C
    CGG
    1123.7
    [m]
    C
    CGG
    1132.5
    [m]
    C
    CGG
    1138.0
    [m]
    DC
    CGG
    1144.0
    [m]
    DC
    CGG
    1150.0
    [m]
    DC
    CGG
    1159.0
    [m]
    DC
    CGG
    1168.0
    [m]
    DC
    CGG
    1177.0
    [m]
    DC
    CGG
    1186.0
    [m]
    DC
    CGG
    1195.0
    [m]
    DC
    CGG
    1204.0
    [m]
    DC
    CGG
    1213.0
    [m]
    DC
    CGG
    1222.0
    [m]
    DC
    CGG
    1231.0
    [m]
    DC
    CGG
    1240.0
    [m]
    DC
    CGG
    1249.0
    [m]
    DC
    CGG
    1258.0
    [m]
    DC
    CGG
    1267.0
    [m]
    DC
    CGG
    1276.0
    [m]
    DC
    CGG
    1285.0
    [m]
    DC
    CGG
    1294.0
    [m]
    DC
    CGG
    1303.0
    [m]
    DC
    CGG
    1312.0
    [m]
    DC
    CGG
    1321.0
    [m]
    DC
    CGG
    1330.0
    [m]
    DC
    CGG
    1339.0
    [m]
    DC
    CGG
    1348.0
    [m]
    DC
    CGG
    1354.0
    [m]
    DC
    CGG
    1360.0
    [m]
    DC
    CGG
    1366.0
    [m]
    DC
    CGG
    1372.0
    [m]
    DC
    CGG
    1378.0
    [m]
    DC
    CGG
    1382.7
    [m]
    C
    CGG
    1390.3
    [m]
    C
    CGG
    1393.2
    [m]
    C
    CGG
    1394.9
    [m]
    C
    CGG
    1397.8
    [m]
    C
    CGG
    1400.9
    [m]
    C
    CGG
    1403.8
    [m]
    C
    CGG
    1404.8
    [m]
    C
    CGG
    1407.6
    [m]
    C
    CGG
    1410.7
    [m]
    C
    CGG
    1412.6
    [m]
    C
    CGG
    1415.6
    [m]
    C
    CGG
    1418.9
    [m]
    C
    CGG
    1421.7
    [m]
    C
    CGG
    1424.7
    [m]
    C
    CGG
    1427.5
    [m]
    C
    CGG
    1430.7
    [m]
    C
    CGG
    1433.9
    [m]
    C
    CGG
    1438.0
    [m]
    DC
    CGG
    1444.0
    [m]
    DC
    CGG
    1450.0
    [m]
    DC
    CGG
    1456.0
    [m]
    DC
    CGG
    1462.0
    [m]
    DC
    CGG
    1468.0
    [m]
    DC
    CGG
    1474.0
    [m]
    DC
    CGG
    1480.0
    [m]
    DC
    CGG
    1486.0
    [m]
    DC
    CGG
    1492.0
    [m]
    DC
    CGG
    1498.0
    [m]
    DC
    CGG
    1504.0
    [m]
    DC
    CGG
    1510.0
    [m]
    DC
    CGG
    1516.0
    [m]
    DC
    CGG
    1522.0
    [m]
    DC
    CGG
    1528.0
    [m]
    DC
    CGG
    1534.0
    [m]
    DC
    CGG
    1540.0
    [m]
    DC
    CGG
    1546.0
    [m]
    DC
    CGG
    1552.0
    [m]
    DC
    CGG
    1558.0
    [m]
    DC
    CGG
    1564.0
    [m]
    DC
    CGG
    1570.0
    [m]
    DC
    CGG
    1576.0
    [m]
    DC
    CGG
    1582.0
    [m]
    DC
    CGG
    1588.0
    [m]
    DC
    CGG
    1594.0
    [m]
    DC
    CGG
    1600.0
    [m]
    DC
    CGG

  • Lithostratigraphy

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CMR HNGS
    972
    1600
    MDT LFA MRMS PA
    985
    1585
    MWD LWD - GR RES DIR INC APWD
    520
    1600
    MWD LWD - TELE INC
    480
    520
    PEX NEXT SS AIT
    450
    973
    RTS SS NEXT PEX
    972
    1600
    USIT CBL
    698
    960

  • 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
    42
    520.0
    36
    520.0
    0.00
    SURF.COND.
    13 3/8
    741.2
    17 1/2
    746.0
    1.43
    FIT
    LINER
    9 5/8
    792.0
    12 1/4
    973.0
    1.54
    FIT
    OPEN HOLE
    1600.0
    8 1/2
    1600.0
    0.00

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    746
    1.14
    14.0
    Exploradrill
    746
    1.30
    19.0
    CMC Spud
    779
    1.14
    13.0
    Exploradrill
    973
    1.17
    15.0
    Exploradrill
    982
    1.18
    15.0
    Exploradrill
    1124
    1.20
    12.0
    Exploradrill
    1134
    1.18
    14.0
    Exploradrill
    1134
    1.20
    17.5
    Exploradrill
    1398
    1.18
    17.0
    Exploradrill
    1435
    1.20
    16.0
    Exploradrill
    1474
    1.18
    15.5
    Exploradrill
    1587
    1.18
    15.5
    Exploradrill
    1601
    1.18
    16.0
    Exploradrill
    1601
    1.20
    16.0
    Exploradrill