Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
31.10.2024 - 01:27
Time of last synchronization with Norwegian Offshore Directorate's internal systems

7324/7-2

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.
    7324/7-2
    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.
    7324/7-2
    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.
    OMV (Norge) 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.
    1515-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.
    85
    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,
    13.04.2014
    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.
    06.07.2014
    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.
    06.07.2016
    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.
    06.07.2016
    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
    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.
    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
    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.
    417.5
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    1730.0
    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).
    1719.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    14.3
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    51
    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.
    MIDDLE 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° 29' 27.09'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    24° 14' 2.56'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    8157493.85
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    412291.83
    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.
    7450

  • Wellbore history
    General
    Well 7324/7-2 was drilled to test the Hanssen prospect in the Hoop Fault Complex in the Barents Sea. The primary objective of well 7324/7-2 was to prove hydrocarbons in the Realgrunnen Subgroup. In addition, the well targeted the deeper Snadd Formation.
    Operations and results
    Wildcat well 7324/7-2 was spudded with the semi-submersible installation Transocean Barents on 13 April 2014 and drilled to TD at 1730 m (1719 m TVD) in the Middle Triassic Snadd Formation. After drilling the top hole to 576 m, the BOP could not be set according to schedule due to damaged Lower Marine Riser Package connector. Attempts to repair this and eventually mobilising a new LMRP connector from shore led to 414.5 hrs NPT. The target tolerance for the Early Carnian Snadd sand was revised from the drilling program. Due to this revision, a steerable drilling system was needed below 1200 m (the 6" hole) for hitting the well path inside the target box. No significant problem was encountered in the operations. The well was drilled with seawater and hi-vis pills down to 521 m and with Glydril mud from 521 m to TD.
    The primary target Stø Formation was encountered at 712 m and was oil bearing down to the oil-water contact, defined at 732.2 m (731.95 m TVD) from fluid scanning. In the secondary target, the Snadd formation, oil shows were described and gas was found but in poor reservoir rocks, and no gas gradient was established.
    Six cores were cut in the well. The two first, 577.5 to 580.9 m in the Kolmule Formation and 672 to 678 m in the Fuglen Formation, were shale cores for geomechanical purposes. Cores 3 to 6 were cut in succession from 710 m in Fuglen cap rock, through the Stø Formation and down to 783.4 m in the Fruholmen Formation. MDT fluid samples were taken at 715 m (oil), 731 m (oil), 731.5 m (oil), 747.5 m (water), 757.7 m (water), 768 m (water), and 883.7 m (water). Fluid scanning at 732 m, 732.2m and 734 m proved water and oil together.
    The well was permanently abandoned on 6 July 2014 as an oil discovery.
    Testing
    One oil DST run was performed in the interval 713 to 727 m in the Stø Formation The test produced 276 Sm3 oil and 9417 Sm3 gas /day through a 48/64" choke. The GOR was 38 Sm3/Sm3, the oil gravity was 0.846g/cm3 (35.7° API), and the gas gravity was 0.731 (air = 1). The CO2 content was 6%. The DST temperature was 16.5 °C.

  • 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]
    577.00
    1730.00

  • 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
    577.5
    580.9
    [m ]
    2
    672.0
    675.9
    [m ]
    3
    710.0
    723.5
    [m ]
    4
    724.0
    739.2
    [m ]
    5
    739.5
    757.4
    [m ]
    6
    757.5
    782.0
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    78.4
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Oil samples at the Norwegian Offshore Directorate
    Oil samples at the Norwegian Offshore Directorate
    Test type
    Bottle number
    Top depth
    MD [m]
    Bottom depth
    MD [m]
    Fluid type
    Test time
    Samples available
    MDT
    714.80
    0.00
    OIL
    NO
    MDT
    731.50
    0.00
    OIL
    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
    518.0
    36
    523.0
    0.00
    SURF.COND.
    20
    571.0
    26
    576.0
    1.36
    FIT
    INTERM.
    9 5/8
    694.0
    12 1/4
    700.0
    1.70
    FIT
    LINER
    7
    1199.0
    8 1/2
    1200.0
    1.99
    FIT
    OPEN HOLE
    1730.0
    6
    1730.0
    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
    713
    727
    19.1
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    17
    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
    276
    9417
    0.846
    0.731
    38

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CMR MDT
    1199
    1720
    CMR MDT GR LEH
    705
    1199
    DP MDT-TLC
    1591
    1655
    FMIHD PPC1 MSIP PPC2 GR LEH
    670
    1199
    GPIT PPC1 MSIP PPC2 GR
    457
    700
    MDT TLC
    715
    883
    MWD - GVR ES PS TS
    576
    700
    MWD - GVR SS IM STS ADN
    576
    1730
    MWD - PP
    457
    522
    MWD - PS ES TS SONVIS
    522
    566
    PEX HRLT ECS FMI
    1199
    1720
    PPC1 MSIP PPC2 MCFL ZAIT HNGS
    1199
    1720
    USIT CBL VDL GR
    583
    1195
    VSP GR
    314
    0
    ZAIT CAL ECS HNGS GR
    500
    700
    ZAIT HRLA PEX HNGS
    705
    1199
    ZVSP
    1121
    1722

  • Lithostratigraphy

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    458
    1.02
    Sea Water
    510
    1.19
    15.0
    GLYDRIL WBM
    521
    1.02
    Sea Water
    540
    1.24
    17.0
    Glydril
    576
    1.14
    23.0
    Glydril
    964
    1.15
    13.0
    Glydril
    1002
    1.14
    Packer Fluid (NaCl brine)
    1200
    1.18
    13.0
    Glydril
    1555
    1.18
    14.0
    Glydril
    1730
    1.18
    12.0
    Glydril