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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33/6-2

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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.
    33/6-2
    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
    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.
    NORTH SEA
    Well name
    Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    33/6-2
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    MN9601M- line 984 & trace 2954
    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.
    Mobil Exploration Norway INC
    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.
    864-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.
    67
    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,
    28.10.1996
    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.
    02.01.1997
    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.
    02.01.1999
    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.
    24.09.2003
    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.
    SHOWS
    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.
    25.3
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    316.7
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3950.0
    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).
    3945.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    5.6
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    137
    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.
    EARLY JURASSIC
    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.
    STATFJORD GP
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    61° 32' 15.87'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    1° 56' 33'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6823304.99
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    443772.57
    UTM zone
    Universal Transverse Mercator zone. Examples of legal values: 31, 32, 33, 34.
    31
    NPDID wellbore
    Norwegian Offshore Directorate's unique id for the wellbore.
    2873

  • Wellbore history
    General
    The 33/6-2 well is located to the north of the Statfjord Nord oil field and to Northwest of Snorre oil field. Agip's 33/6-1 well, which was plugged and abandoned dry, was drilled approximately 4 km to the west.
    The primary objective of the well was the Upper Jurassic (Volgian) Intra-Draupne "Munin sandstone unit" of the Draupne Formation. It was designed to find commercial hydrocarbons in a structural/stratigraphic trap where the Base Munin sub crops the base Cretaceous unconformity. The secondary objective of the well was to test the reserve potential in the Brent Group, intra Dunlin Group and Statfjord Formation sandstones.
    Operations and results
    Exploration well 33/6-2 was spudded with the semi-submersible installation "Byford Dolphin" on 28 October 1996 and drilled to TD at 3950 m in the Early Jurassic Statfjord Formation. The well was drilled with seawater and hi-vis pills down to 991 m, with KCl/glycol ("ANCO 208") mud from 991 m to 2150 m, and with KCl/polymer/glycol ("ANCO 208") from 2150 m to TD. In the Upper Jurassic two cores were cut in sandstones of the Intra-Draupne sandstone unit. Whilst there were some shows, the sandstones proved to be generally low porosity. In the Early - Middle Jurassic Brent and Dunlin Group sandstones no oil shows were observed and no cores were taken. Weak shows were however observed in shaley/carbonaceous lithologies in this interval, indicating some in-situ generated hydrocarbons. No shows were observed in the Statfjord Formation. RFT fluid samples were retrieved from 3550 m in the Intra-Draupne Sandstone and from 3622 m in the Brent Group. By adding thiocyanate to the mud as a tracer it could be established that both samples were heavily contaminated by mud (70 % ? 80 %).
    The well was plugged and abandoned as a dry hole with shows on 2 January 1997.
    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]
    1000.00
    3950.00

  • 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
    3500.0
    3519.7
    [m ]
    2
    3540.0
    3551.9
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    31.5
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 3500-3505m
    Core photo at depth: 3505-3510m
    Core photo at depth: 3510-3515m
    Core photo at depth: 3515-3519m
    Core photo at depth: 3540-3545m
    3500-3505m
    3505-3510m
    3510-3515m
    3515-3519m
    3540-3545m
    Core photo at depth: 3545-3550m
    Core photo at depth: 3550-3552m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    3545-3550m
    3550-3552m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1500.0
    [m]
    DC
    RRI
    1510.0
    [m]
    DC
    RRI
    1520.0
    [m]
    DC
    RRI
    1530.0
    [m]
    DC
    RRI
    1540.0
    [m]
    DC
    RRI
    1550.0
    [m]
    DC
    RRI
    1560.0
    [m]
    DC
    RRI
    1570.0
    [m]
    DC
    RRI
    1580.0
    [m]
    DC
    RRI
    1590.0
    [m]
    DC
    RRI
    1600.0
    [m]
    DC
    RRI
    1610.0
    [m]
    DC
    RRI
    1620.0
    [m]
    DC
    RRI
    1630.0
    [m]
    DC
    RRI
    1640.0
    [m]
    DC
    RRI
    1650.0
    [m]
    DC
    RRI
    1660.0
    [m]
    DC
    RRI
    1670.0
    [m]
    DC
    RRI
    1680.0
    [m]
    DC
    RRI
    1690.0
    [m]
    DC
    RRI
    1700.0
    [m]
    DC
    RRI
    1710.0
    [m]
    DC
    RRI
    1720.0
    [m]
    DC
    RRI
    1730.0
    [m]
    DC
    RRI
    1740.0
    [m]
    DC
    RRI
    1750.0
    [m]
    DC
    RRI
    1760.0
    [m]
    DC
    RRI
    1770.0
    [m]
    DC
    RRI
    1780.0
    [m]
    DC
    RRI
    1790.0
    [m]
    DC
    RRI
    1800.0
    [m]
    DC
    RRI
    1810.0
    [m]
    DC
    RRI
    1830.0
    [m]
    DC
    RRI
    1840.0
    [m]
    DC
    RRI
    1850.0
    [m]
    DC
    RRI
    1860.0
    [m]
    DC
    RRI
    1870.0
    [m]
    DC
    RRI
    1880.0
    [m]
    DC
    RRI
    1890.0
    [m]
    DC
    RRI
    1900.0
    [m]
    DC
    RRI
    1910.0
    [m]
    DC
    RRI
    1920.0
    [m]
    DC
    RRI
    1930.0
    [m]
    DC
    RRI
    1940.0
    [m]
    DC
    RRI
    1970.0
    [m]
    DC
    RRI
    2000.0
    [m]
    DC
    RRI
    2030.0
    [m]
    DC
    RRI
    2060.0
    [m]
    DC
    RRI
    2090.0
    [m]
    DC
    RRI
    2150.0
    [m]
    DC
    RRI
    2180.0
    [m]
    DC
    RRI
    2210.0
    [m]
    DC
    RRI
    2240.0
    [m]
    DC
    RRI
    2270.0
    [m]
    DC
    RRI
    2300.0
    [m]
    DC
    RRI
    2330.0
    [m]
    DC
    RRI
    2354.0
    [m]
    DC
    RRI
    2360.0
    [m]
    DC
    RRI
    2390.0
    [m]
    DC
    RRI
    2420.0
    [m]
    DC
    RRI
    2450.0
    [m]
    DC
    RRI
    2480.0
    [m]
    DC
    RRI
    2510.0
    [m]
    DC
    RRI
    2540.0
    [m]
    DC
    RRI
    2570.0
    [m]
    DC
    RRI
    2600.0
    [m]
    DC
    RRI
    2630.0
    [m]
    DC
    RRI
    2660.0
    [m]
    DC
    RRI
    2690.0
    [m]
    DC
    RRI
    2720.0
    [m]
    DC
    RRI
    2750.0
    [m]
    DC
    RRI
    2780.0
    [m]
    DC
    RRI
    2810.0
    [m]
    DC
    RRI
    2840.0
    [m]
    DC
    RRI
    2870.0
    [m]
    DC
    RRI
    2900.0
    [m]
    DC
    RRI
    2930.0
    [m]
    DC
    RRI
    2960.0
    [m]
    DC
    RRI
    2990.0
    [m]
    DC
    RRI
    3020.0
    [m]
    DC
    RRI
    3050.0
    [m]
    DC
    RRI
    3080.0
    [m]
    DC
    RRI
    3110.0
    [m]
    DC
    RRI
    3140.0
    [m]
    DC
    RRI
    3170.0
    [m]
    DC
    RRI
    3200.0
    [m]
    DC
    RRI
    3232.0
    [m]
    DC
    RRI
    3236.0
    [m]
    DC
    RRI
    3242.0
    [m]
    DC
    RRI
    3248.0
    [m]
    DC
    RRI
    3260.0
    [m]
    DC
    RRI
    3266.0
    [m]
    DC
    RRI
    3272.0
    [m]
    DC
    RRI
    3278.0
    [m]
    DC
    RRI
    3284.0
    [m]
    DC
    RRI
    3290.0
    [m]
    DC
    RRI
    3296.0
    [m]
    DC
    RRI
    3302.0
    [m]
    DC
    RRI
    3308.0
    [m]
    DC
    RRI
    3386.0
    [m]
    DC
    RRI
    3392.0
    [m]
    DC
    RRI
    3398.0
    [m]
    DC
    RRI
    3404.0
    [m]
    DC
    RRI
    3410.0
    [m]
    DC
    RRI
    3422.0
    [m]
    DC
    RRI
    3428.0
    [m]
    DC
    RRI
    3434.0
    [m]
    DC
    RRI
    3446.0
    [m]
    DC
    RRI
    3452.0
    [m]
    DC
    RRI
    3456.0
    [m]
    DC
    RRI
    3462.0
    [m]
    DC
    RRI
    3468.0
    [m]
    DC
    RRI
    3474.0
    [m]
    DC
    RRI
    3480.0
    [m]
    DC
    RRI
    3485.0
    [m]
    SWC
    RRI
    3492.0
    [m]
    DC
    RRI
    3493.0
    [m]
    SWC
    RRI
    3498.0
    [m]
    DC
    RRI
    3500.0
    [m]
    DC
    RRI
    3502.0
    [m]
    DC
    RRI
    3504.0
    [m]
    DC
    RRI
    3506.0
    [m]
    DC
    RRI
    3510.0
    [m]
    DC
    RRI
    3512.0
    [m]
    DC
    RRI
    3513.0
    [m]
    DC
    RRI
    3516.0
    [m]
    DC
    RRI
    3517.0
    [m]
    DC
    RRI
    3522.0
    [m]
    DC
    RRI
    3528.0
    [m]
    DC
    RRI
    3531.0
    [m]
    SWC
    RRI
    3535.0
    [m]
    SWC
    RRI
    3540.0
    [m]
    C
    RRI
    3543.0
    [m]
    DC
    RRI
    3544.0
    [m]
    DC
    RRI
    3546.0
    [m]
    DC
    RRI
    3547.0
    [m]
    DC
    RRI
    3549.0
    [m]
    DC
    RRI
    3550.0
    [m]
    C
    RRI
    3551.0
    [m]
    DC
    RRI
    3552.0
    [m]
    DC
    RRI
    3556.0
    [m]
    SWC
    RRI
    3559.0
    [m]
    SWC
    RRI
    3564.0
    [m]
    DC
    RRI
    3570.0
    [m]
    DC
    RRI
    3578.0
    [m]
    DC
    RRI
    3583.0
    [m]
    SWC
    RRI
    3588.0
    [m]
    DC
    RRI
    3598.0
    [m]
    SWC
    RRI
    3599.0
    [m]
    SWC
    RRI
    3606.0
    [m]
    DC
    RRI
    3612.0
    [m]
    DC
    RRI
    3617.0
    [m]
    DC
    RRI
    3619.0
    [m]
    SWC
    RRI
    3625.0
    [m]
    SWC
    RRI
    3708.0
    [m]
    DC
    RRI
    3714.0
    [m]
    DC
    RRI
    3720.0
    [m]
    DC
    RRI
    3724.0
    [m]
    DC
    RRI
    3724.0
    [m]
    SWC
    RRI
    3736.0
    [m]
    SWC
    RRI
    3738.0
    [m]
    DC
    RRI
    3744.0
    [m]
    DC
    RRI
    3750.0
    [m]
    DC
    RRI
    3756.0
    [m]
    DC
    RRI
    3762.0
    [m]
    DC
    RRI
    3762.0
    [m]
    SWC
    RRI
    3768.0
    [m]
    DC
    RRI
    3774.0
    [m]
    DC
    RRI
    3777.0
    [m]
    SWC
    RRI
    3786.0
    [m]
    DC
    RRI
    3792.0
    [m]
    DC
    RRI
    3797.0
    [m]
    DC
    RRI
    3797.0
    [m]
    SWC
    RRI
    3804.0
    [m]
    DC
    RRI
    3810.0
    [m]
    DC
    RRI
    3816.0
    [m]
    DC
    RRI
    3822.0
    [m]
    DC
    RRI
    3825.0
    [m]
    DC
    RRI
    3834.0
    [m]
    DC
    RRI
    3840.0
    [m]
    DC
    RRI
    3846.0
    [m]
    DC
    RRI
    3852.0
    [m]
    DC
    RRI
    3858.0
    [m]
    DC
    RRI
    3864.0
    [m]
    DC
    RRI
    3870.0
    [m]
    DC
    RRI
    3870.0
    [m]
    SWC
    RRI
    3872.0
    [m]
    SWC
    RRI
    3876.0
    [m]
    DC
    RRI
    3880.0
    [m]
    SWC
    RRI
    3888.0
    [m]
    DC
    RRI
    3894.0
    [m]
    DC
    RRI
    3901.0
    [m]
    DC
    RRI
    3901.0
    [m]
    SWC
    RRI
    3906.0
    [m]
    DC
    RRI
    3924.0
    [m]
    DC
    RRI
    3930.0
    [m]
    DC
    RRI
    3936.0
    [m]
    DC
    RRI
    3942.0
    [m]
    DC
    RRI
    3948.0
    [m]
    DC
    RRI

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.63

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    1.90
    pdf
    1.95
    pdf
    1.97
    pdf
    1.65

  • Documents – reported by the production licence (period for duty of secrecy expired)
    Documents – reported by the production licence (period for duty of secrecy expired)
    Document name
    Document format
    Document size [MB]
    pdf
    3.49
    pdf
    64.81

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    - GR AMS
    986
    2142
    - GR AMS
    2137
    3457
    CMR DSI NGT AMS
    3440
    3953
    CST GR
    2153
    3445
    CST GR
    3481
    3916
    FMS AIT LDT CNL MSFL GR AMS
    3440
    3953
    MDT GR
    3493
    3622
    MWD LWD - D EWR GR
    342
    991
    MWD LWD - RDG EWR GR
    342
    990
    MWD LWD - RGD EWR GR
    976
    3950
    PI DSI MSFL LDL CNL GPIT EDAC -
    986
    2142
    PI DSI MSFL LDL CNL GPIT EDAC -
    2137
    3457
    RFT GR
    3493
    3619
    VSP - WSC
    1137
    2947

  • 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
    390.0
    36
    390.0
    0.00
    LOT
    SURF.COND.
    20
    986.0
    26
    991.0
    0.00
    LOT
    INTERM.
    13 3/8
    2138.7
    17 1/2
    2150.0
    0.00
    LOT
    INTERM.
    9 5/8
    3440.0
    12 1/4
    3453.0
    0.00
    LOT
    OPEN HOLE
    3950.0
    8 1/2
    3950.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    585
    1.03
    30.0
    SEAWATER
    990
    1.02
    30.0
    SEAWATER
    991
    1.12
    25.0
    SEAWATER
    1168
    1.33
    25.0
    SEAWATER
    1468
    1.37
    33.0
    SEAWATER
    1812
    1.37
    27.0
    SEAWATER
    2020
    1.42
    28.0
    SEAWATER
    2150
    1.50
    33.0
    SEAWATER
    2296
    1.50
    23.0
    SEAWATER
    2390
    1.51
    26.0
    SEAWATER
    2406
    1.51
    26.0
    SEAWATER
    2523
    1.50
    19.0
    SEAWATER
    2679
    1.50
    24.0
    SEAWATER
    2716
    1.49
    23.0
    SEAWATER
    2788
    1.48
    25.0
    SEAWATER
    2891
    1.49
    25.0
    SEAWATER
    2956
    1.49
    29.0
    SEAWATER
    3181
    1.50
    21.0
    SEAWATER
    3453
    1.50
    21.0
    SEAWATER
    3453
    1.50
    28.0
    SEAWATER
    3453
    1.50
    26.0
    SEAWATER
    3453
    1.51
    22.0
    SEAWATER
    3453
    1.50
    21.0
    SEAWATER
    3455
    0.00
    SEAWATER
    3494
    1.50
    22.0
    SEAWATER
    3508
    1.49
    23.0
    SEAWATER
    3553
    1.51
    17.0
    SEAWATER
    3553
    1.50
    17.0
    SEAWATER
    3572
    1.50
    17.0
    SEAWATER
    3667
    1.51
    18.0
    SEAWATER
    3761
    1.50
    21.0
    SEAWATER
    3776
    1.50
    21.0
    SEAWATER
    3784
    1.50
    21.0
    SEAWATER
    3845
    1.51
    23.0
    SEAWATER
    3927
    1.50
    22.0
    SEAWATER
    3950
    1.50
    25.0
    SEAWATER

  • Pressure plots
    Pressure plots
    The pore pressure data is sourced from well logs if no other source is specified. In some wells where pore pressure logs do not exist, information from Drill stem tests and kicks have been used. The data has been reported to the NPD, and further processed and quality controlled by IHS Markit.
    Pressure plots
    Document name
    Document format
    Document size [MB]
    PDF
    0.22