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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31/2-19 S

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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.
    31/2-19 S
    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.
    31/2-19
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    NH 92 - INLINE 2920 & CROSSLINE 3662
    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.
    Norsk Hydro Produksjon 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.
    844-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.
    44
    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,
    08.05.1996
    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.
    13.07.1996
    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.
    13.07.1998
    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.
    31.10.2003
    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.
    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.
    22.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    344.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4114.0
    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).
    3669.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    38.6
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    117
    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.
    60° 54' 37.5'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    3° 22' 17.32'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6753026.19
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    520149.18
    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.
    2798

  • Wellbore history
    General
    Well 31/2-19 S is located in the Troll West area some few kilometres to the northwest of the Troll Field. It was drilled to test the hydrocarbon potential of the "S-structure". The primary targets were the Jurassic Sognefjord and Fensfjord Formations, and the Brent Group. Secondary targets were the Paleocene (Lista Formation), the Dunlin Group and the Statfjord Formation.
    Operations and results
    Exploration well 31/2-19 S was spudded with the semi-submersible installation "West Vanguard" on 8 May and drilled to TD at 4114 m (3669 m TVD RKB) in the Early Jurassic Statfjord Formation The well was drilled with seawater and hi-vis bentonite sweeps down to 1316 m and with KCl/PHPA polymer mud from 1316 m to TD.
    The well encountered 131 m of Intra Lista Formation sandstone, and a 30-40 m sandy interval of poor reservoir quality in the Cretaceous Rødby Formation. Two of the primary prospective levels, the Sognefjord and Fensfjord Formations of the Viking Group were not deposited; instead more than 700 m with the distal Heather formation was penetrated. The Brent Group and Dunlin Group sandstones, and the Statfjord Formation were encountered according to the prognosis. The well was found to be dry (no moveable hydrocarbons) with only weak hydrocarbon shows observed in the Intra Lista Formation sandstone and in sandstones of the Viking and Brent Groups.
    Five cores were cut, two of them in the Lista Formation, the third in the Rødby Formation, and the last two ones in the Heater Formation. Pressure points were obtained by the HP gauge of the RFT tool. In the Lista Sandstone, a water gradient of 0.99 g/cc was found. In the Cretaceous, no gradient could be defined due to only tight points. In the Brent Group (the Ness and Etive formation equivalents) a water gradient of 1.01 g/cc was found. In the Dunlin Group three good RFT points were achieved. The two deepest ones (in the Amundsen Formation) indicated a water gradient of 0.98 g/cc. No fluid samples were taken. The well was permanently abandoned on 13 July as a dry well with weak shows.
    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]
    1320.00
    4114.00

  • 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
    1745.0
    1748.4
    [m ]
    2
    1748.4
    1755.6
    [m ]
    3
    2515.6
    2517.2
    [m ]
    4
    3190.0
    3190.9
    [m ]
    5
    3196.0
    3214.8
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    31.9
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 1745-1748m
    Core photo at depth: 1748-1752m
    Core photo at depth: 1752-1755m
    Core photo at depth: 2515-2517m
    Core photo at depth: 3190-3191m
    1745-1748m
    1748-1752m
    1752-1755m
    2515-2517m
    3190-3191m
    Core photo at depth: 3196-3201m
    Core photo at depth: 3201-3206m
    Core photo at depth: 3206-3211m
    Core photo at depth: 3211-3214m
    Core photo at depth:  
    3196-3201m
    3201-3206m
    3206-3211m
    3211-3214m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1320.0
    [m]
    DC
    RRI
    1340.0
    [m]
    DC
    RRI
    1360.0
    [m]
    DC
    RRI
    1380.0
    [m]
    DC
    RRI
    1400.0
    [m]
    DC
    RRI
    1420.0
    [m]
    DC
    RRI
    1440.0
    [m]
    DC
    RRI
    1460.0
    [m]
    DC
    RRI
    1480.0
    [m]
    DC
    RRI
    1500.0
    [m]
    DC
    RRI
    1520.0
    [m]
    DC
    RRI
    1521.0
    [m]
    DC
    RRI
    1560.0
    [m]
    SWC
    RRI
    1580.0
    [m]
    DC
    RRI
    1600.0
    [m]
    DC
    RRI
    1610.0
    [m]
    DC
    RRI
    1620.0
    [m]
    DC
    RRI
    1625.0
    [m]
    SWC
    RRI
    1632.0
    [m]
    SWC
    RRI
    1637.0
    [m]
    SWC
    RRI
    1650.0
    [m]
    DC
    RRI
    1660.0
    [m]
    DC
    RRI
    1678.0
    [m]
    SWC
    RRI
    1699.0
    [m]
    SWC
    RRI
    1710.0
    [m]
    DC
    RRI
    1719.0
    [m]
    SWC
    RRI
    1730.0
    [m]
    DC
    RRI
    1740.0
    [m]
    DC
    RRI
    1750.0
    [m]
    DC
    RRI
    1761.0
    [m]
    SWC
    RRI
    1770.0
    [m]
    DC
    RRI
    1780.0
    [m]
    DC
    RRI
    1792.0
    [m]
    SWC
    RRI
    1800.0
    [m]
    DC
    RRI
    1812.0
    [m]
    SWC
    RRI
    1830.0
    [m]
    SWC
    RRI
    1855.0
    [m]
    SWC
    RRI
    1861.0
    [m]
    SWC
    RRI
    1967.0
    [m]
    SWC
    RRI
    1982.0
    [m]
    SWC
    RRI
    2017.0
    [m]
    SWC
    RRI
    2035.0
    [m]
    SWC
    RRI
    2059.0
    [m]
    SWC
    RRI
    2075.0
    [m]
    SWC
    RRI
    2099.0
    [m]
    SWC
    RRI
    2120.0
    [m]
    SWC
    RRI
    2125.0
    [m]
    SWC
    RRI
    2130.0
    [m]
    SWC
    RRI
    2147.0
    [m]
    SWC
    RRI
    2180.0
    [m]
    SWC
    RRI
    2230.0
    [m]
    SWC
    RRI
    2276.0
    [m]
    SWC
    RRI
    2297.0
    [m]
    SWC
    RRI
    2300.0
    [m]
    DC
    RRI
    2315.0
    [m]
    SWC
    RRI
    2340.0
    [m]
    SWC
    RRI
    2380.0
    [m]
    SWC
    RRI
    2400.0
    [m]
    DC
    RRI
    2416.0
    [m]
    SWC
    RRI
    2433.0
    [m]
    SWC
    RRI
    2450.0
    [m]
    DC
    RRI
    2462.0
    [m]
    SWC
    RRI
    2472.0
    [m]
    SWC
    RRI
    2478.0
    [m]
    SWC
    RRI
    2500.0
    [m]
    DC
    RRI
    2540.0
    [m]
    DC
    RRI
    2600.0
    [m]
    DC
    RRI
    2620.0
    [m]
    DC
    RRI
    2630.0
    [m]
    DC
    RRI
    2640.0
    [m]
    SWC
    RRI
    2650.0
    [m]
    DC
    RRI
    2658.0
    [m]
    SWC
    RRI
    2660.0
    [m]
    DC
    RRI
    2670.0
    [m]
    DC
    RRI
    2682.0
    [m]
    SWC
    RRI
    2690.0
    [m]
    DC
    RRI
    2703.0
    [m]
    SWC
    RRI
    2710.0
    [m]
    SWC
    RRI
    2720.0
    [m]
    DC
    RRI
    2725.0
    [m]
    SWC
    RRI
    2733.0
    [m]
    SWC
    RRI
    2740.0
    [m]
    SWC
    RRI
    2750.0
    [m]
    SWC
    RRI
    2760.0
    [m]
    SWC
    RRI
    2772.0
    [m]
    SWC
    RRI
    2780.0
    [m]
    DC
    RRI
    2790.0
    [m]
    SWC
    RRI
    2800.0
    [m]
    DC
    RRI
    2810.0
    [m]
    DC
    RRI
    2814.0
    [m]
    DC
    RRI
    2820.0
    [m]
    DC
    RRI
    2830.0
    [m]
    DC
    RRI
    2840.0
    [m]
    DC
    RRI
    2850.0
    [m]
    DC
    RRI
    2860.0
    [m]
    DC
    RRI
    2870.0
    [m]
    DC
    RRI
    2875.0
    [m]
    DC
    RRI
    2880.0
    [m]
    DC
    RRI
    2890.0
    [m]
    DC
    RRI
    2898.0
    [m]
    DC
    RRI
    2900.0
    [m]
    DC
    RRI
    2910.0
    [m]
    DC
    RRI
    2920.0
    [m]
    DC
    RRI
    2930.0
    [m]
    DC
    RRI
    2940.0
    [m]
    DC
    RRI
    2942.0
    [m]
    DC
    RRI
    2950.0
    [m]
    DC
    RRI
    2960.0
    [m]
    DC
    RRI
    2970.0
    [m]
    DC
    RRI
    2972.0
    [m]
    DC
    RRI
    2980.0
    [m]
    DC
    RRI
    2983.0
    [m]
    DC
    RRI
    2990.0
    [m]
    DC
    RRI
    3000.0
    [m]
    DC
    RRI
    3010.0
    [m]
    DC
    RRI
    3020.0
    [m]
    DC
    RRI
    3030.0
    [m]
    DC
    RRI
    3032.0
    [m]
    DC
    RRI
    3042.0
    [m]
    DC
    RRI
    3050.0
    [m]
    DC
    RRI
    3060.0
    [m]
    DC
    RRI
    3070.0
    [m]
    DC
    RRI
    3080.0
    [m]
    DC
    RRI
    3090.0
    [m]
    DC
    RRI
    3100.0
    [m]
    DC
    RRI
    3110.0
    [m]
    DC
    RRI
    3130.0
    [m]
    SWC
    RRI
    3140.0
    [m]
    DC
    RRI
    3150.0
    [m]
    SWC
    RRI
    3160.0
    [m]
    DC
    RRI
    3170.0
    [m]
    SWC
    RRI
    3178.0
    [m]
    SWC
    RRI
    3218.0
    [m]
    SWC
    RRI
    3226.0
    [m]
    SWC
    RRI
    3244.0
    [m]
    SWC
    RRI
    3256.0
    [m]
    SWC
    RRI
    3260.0
    [m]
    SWC
    RRI
    3271.0
    [m]
    SWC
    RRI
    3280.0
    [m]
    DC
    RRI
    3304.0
    [m]
    SWC
    RRI
    3311.0
    [m]
    SWC
    RRI
    3321.0
    [m]
    SWC
    RRI
    3330.0
    [m]
    DC
    RRI
    3339.0
    [m]
    SWC
    RRI
    3340.0
    [m]
    DC
    RRI
    3350.0
    [m]
    SWC
    RRI
    3362.0
    [m]
    SWC
    RRI
    3379.0
    [m]
    SWC
    RRI
    3391.0
    [m]
    SWC
    RRI
    3400.0
    [m]
    DC
    RRI
    3408.0
    [m]
    SWC
    RRI
    3421.0
    [m]
    SWC
    RRI
    3429.0
    [m]
    SWC
    RRI
    3440.0
    [m]
    DC
    RRI
    3450.0
    [m]
    DC
    RRI
    3458.0
    [m]
    SWC
    RRI
    3470.0
    [m]
    DC
    RRI
    3478.0
    [m]
    SWC
    RRI
    3495.0
    [m]
    SWC
    RRI
    3500.0
    [m]
    DC
    RRI
    3510.0
    [m]
    DC
    RRI
    3520.0
    [m]
    DC
    RRI
    3530.0
    [m]
    DC
    RRI
    3540.0
    [m]
    DC
    RRI
    3550.0
    [m]
    DC
    RRI
    3552.0
    [m]
    SWC
    RRI
    3562.0
    [m]
    SWC
    RRI
    3567.0
    [m]
    SWC
    RRI
    3589.0
    [m]
    SWC
    RRI
    3600.0
    [m]
    DC
    RRI
    3610.0
    [m]
    DC
    RRI
    3621.0
    [m]
    SWC
    RRI
    3630.0
    [m]
    DC
    RRI
    3646.0
    [m]
    SWC
    RRI
    3658.0
    [m]
    SWC
    RRI
    3670.0
    [m]
    DC
    RRI
    3683.0
    [m]
    SWC
    RRI
    3690.0
    [m]
    DC
    RRI
    3700.0
    [m]
    DC
    RRI
    3710.0
    [m]
    DC
    RRI
    3720.0
    [m]
    DC
    RRI
    3728.0
    [m]
    SWC
    RRI
    3756.0
    [m]
    SWC
    RRI
    3770.0
    [m]
    DC
    RRI
    3786.0
    [m]
    SWC
    RRI
    3800.0
    [m]
    DC
    RRI
    3820.0
    [m]
    DC
    RRI
    3840.0
    [m]
    DC
    RRI
    3867.0
    [m]
    SWC
    RRI
    3892.0
    [m]
    SWC
    RRI
    3900.0
    [m]
    DC
    RRI
    3920.0
    [m]
    DC
    RRI
    3939.0
    [m]
    SWC
    RRI
    3960.0
    [m]
    DC
    RRI
    3980.0
    [m]
    DC
    RRI
    3990.0
    [m]
    SWC
    RRI
    4000.0
    [m]
    DC
    RRI
    4020.0
    [m]
    DC
    RRI
    4040.0
    [m]
    DC
    RRI
    4060.0
    [m]
    DC
    RRI
    4075.0
    [m]
    SWC
    RRI
    4100.0
    [m]
    DC
    RRI
    4114.0
    [m]
    DC
    RRI

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.71

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    1.78
    pdf
    1.72
    pdf
    0.70

  • 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
    24.02

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CST GR
    1560
    2075
    CST GR
    2099
    3070
    CST GR
    3150
    4070
    DLL MSFL DSI LDL SNL NGT AMS SP
    1270
    3100
    DLL MSFL LDL CNL BHC NGT AMS SP
    2970
    4111
    FMS GR AMS
    3087
    4107
    FMS MSFL GR AMS
    1309
    3098
    MSFL GR AMS
    2670
    2850
    MWD - GR RES DIR
    366
    4100
    RFT GR AMS
    1764
    2496
    RFT GR AMS
    1870
    2471
    RFT GR AMS
    3178
    3922
    VSP
    1290
    3090
    VSP
    2980
    4090

  • 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
    428.5
    36
    428.5
    0.00
    LOT
    INTERM.
    13 3/8
    1316.0
    17 1/2
    1316.0
    0.00
    LOT
    INTERM.
    9 5/8
    3118.0
    12 1/4
    3118.0
    0.00
    LOT
    OPEN HOLE
    4114.0
    8 1/2
    4114.0
    1.64
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    428
    1.20
    WATER BASED
    1316
    1.06
    WATER BASED
    1504
    1.25
    13.0
    WATER BASED
    1745
    1.25
    14.0
    WATER BASED
    1748
    1.25
    20.0
    WATER BASED
    2164
    1.26
    20.0
    WATER BASED
    2518
    1.26
    21.0
    WATER BASED
    2620
    1.25
    21.0
    WATER BASED
    2917
    1.25
    24.0
    WATER BASED
    2920
    1.25
    WATER BASED
    3118
    1.30
    24.0
    WATER BASED
    3196
    1.30
    20.0
    WATER BASED
    3203
    1.30
    19.0
    WATER BASED
    3453
    1.30
    18.0
    WATER BASED
    4114
    1.30
    17.0
    WATER BASED

  • 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
    0.24