Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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25.11.2024 - 01:30
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6706/11-1

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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.
    6706/11-1
    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
    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.
    NORWEGIAN SEA
    Well name
    Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    6706/11-1
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    3D- ST 9603- INLINE 3840& CROSSLINE 2090
    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.
    Den norske stats oljeselskap a.s
    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.
    907-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.
    162
    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,
    12.10.1997
    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.
    22.03.1998
    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.
    22.03.2000
    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.
    15.11.2001
    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.
    26.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    1238.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4317.0
    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).
    4306.0
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    115
    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 CRETACEOUS
    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.
    LANGE FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    67° 4' 24.77'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    6° 27' 47.7'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7442018.41
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    389745.19
    UTM zone
    Universal Transverse Mercator zone. Examples of legal values: 31, 32, 33, 34.
    32
    NPDID wellbore
    Norwegian Offshore Directorate's unique id for the wellbore.
    3202

  • Wellbore history
    General
    Well 6706/11-1 was drilled on the Ægir prospect on the Vema Dome in the north of the Vøring basin. The main objectives for the well were to test the hydrocarbon potential of the Ægir prospect and to obtain data to allow for efficient exploration of the remaining licence area.
    Operations and results
    The original well was spudded and drilled to a total depth of 1988 m MD RT, with the 30" casing at 1340 m and 20" casing at 1685 m, respectively. This well was abandoned due to technical problems (no BOP test was obtained). The well was named 6706/11-1Z. The 1st respud was drilled to 1740 m MD RT. The 30" and the 20" casings were set at 1340 m and 1711 m, respectively. Technical problems were again the reason for abandoning this well. A bootstrap tool used to tighten the conductor and the 20" casings got stuck. The 1st re-spud was named 6706/11-1Y. The second and successful re-spud was named 6706/11-1. The well was drilled with seawater and hi-vis pills down to 1648 m and with Barasilc silicate mud from 1648 m to TD. In the section from 2255 m to 3476 m GEM GP (glycols) were added to the Barasilc mud. The Brygge Formation consisted mainly of ooze sediments with very low densities (bulk density of 1.4 g/cm3 was measured). Small fractures/ faults were interpreted in the intersection between Paleocene sandstone and the Springar Formation. It was assumed that the ooze lithology as well as unstable and fractured formation were the predomominant cause of the drilling problems that were encountered in the top section of the wellbores.
    The dominant part of the sediments proved to be of Cretaceous age. The well intersects a single fault just below the base Quaternary and several faults at base Tertiary level. Both the Nise Sandstone 1 and the Nise Sandstone 2 formations were developed. No significant amounts of hydrocarbons were encountered only small amounts of very dry gas in an MDT sample from 3740 m. Five cores were cut in the NISE Formation. The well was permanently plugged and abandoned as a dry hole.
    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]
    1660.00
    4311.00

  • 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
    2297.0
    2304.2
    [m ]
    2
    2306.5
    2323.0
    [m ]
    3
    3107.5
    3112.0
    [m ]
    4
    3112.0
    3136.7
    [m ]
    5
    3744.0
    3749.6
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    58.5
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 2297-2302m
    Core photo at depth: 2302-2304m
    Core photo at depth: 2306-2311m
    Core photo at depth: 2311-2316m
    Core photo at depth: 2316-2321m
    2297-2302m
    2302-2304m
    2306-2311m
    2311-2316m
    2316-2321m
    Core photo at depth: 2321-2323m
    Core photo at depth: 3107-3212m
    Core photo at depth: 3112-3117m
    Core photo at depth: 3117-3122m
    Core photo at depth: 3122-3127m
    2321-2323m
    3107-3212m
    3112-3117m
    3117-3122m
    3122-3127m
    Core photo at depth: 3127-3232m
    Core photo at depth: 3132-3136m
    Core photo at depth: 3744-3749m
    Core photo at depth: 3749-3750m
    Core photo at depth:  
    3127-3232m
    3132-3136m
    3744-3749m
    3749-3750m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1660.0
    [m]
    DC
    RRI
    1670.0
    [m]
    DC
    RRI
    1690.0
    [m]
    DC
    RRI
    1700.0
    [m]
    DC
    RRI
    1720.0
    [m]
    DC
    RRI
    1730.0
    [m]
    DC
    RRI
    1750.0
    [m]
    DC
    RRI
    1760.0
    [m]
    DC
    RRI
    1780.0
    [m]
    DC
    RRI
    1790.0
    [m]
    DC
    RRI
    1810.0
    [m]
    DC
    RRI
    1830.0
    [m]
    DC
    RRI
    1840.0
    [m]
    DC
    RRI
    1860.0
    [m]
    DC
    RRI
    1870.0
    [m]
    DC
    RRI
    1885.0
    [m]
    DC
    RRI
    1900.0
    [m]
    DC
    RRI
    1920.0
    [m]
    DC
    RRI
    1930.0
    [m]
    DC
    RRI
    1955.0
    [m]
    DC
    RRI
    1960.0
    [m]
    DC
    RRI
    1975.0
    [m]
    DC
    RRI
    1990.0
    [m]
    DC
    RRI
    2005.0
    [m]
    DC
    RRI
    2020.0
    [m]
    DC
    RRI
    2035.0
    [m]
    DC
    RRI
    2050.0
    [m]
    DC
    RRI
    2065.0
    [m]
    DC
    RRI
    2085.0
    [m]
    DC
    RRI
    2090.0
    [m]
    DC
    RRI
    2110.0
    [m]
    DC
    RRI
    2125.0
    [m]
    DC
    RRI
    2140.0
    [m]
    DC
    RRI
    2155.0
    [m]
    DC
    RRI
    2170.0
    [m]
    DC
    RRI
    2185.0
    [m]
    DC
    RRI
    2203.0
    [m]
    DC
    RRI
    2215.0
    [m]
    DC
    RRI
    2230.0
    [m]
    DC
    RRI
    2245.0
    [m]
    DC
    RRI
    2255.0
    [m]
    DC
    RRI
    2266.0
    [m]
    SWC
    OD
    2275.0
    [m]
    DC
    RRI
    2286.5
    [m]
    SWC
    OD
    2295.5
    [m]
    SWC
    OD
    2297.7
    [m]
    C
    RRI
    2299.0
    [m]
    C
    RRI
    2301.0
    [m]
    C
    RRI
    2303.0
    [m]
    C
    RRI
    2307.3
    [m]
    C
    RRI
    2317.5
    [m]
    C
    RRI
    2321.0
    [m]
    C
    RRI
    2336.0
    [m]
    DC
    RRI
    2352.0
    [m]
    DC
    RRI
    2366.0
    [m]
    DC
    RRI
    2378.0
    [m]
    DC
    RRI
    2396.0
    [m]
    DC
    RRI
    2408.0
    [m]
    DC
    RRI
    2426.0
    [m]
    DC
    RRI
    2442.5
    [m]
    SWC
    OD
    2450.0
    [m]
    DC
    RRI
    2501.0
    [m]
    DC
    RRI
    2522.0
    [m]
    DC
    RRI
    2534.0
    [m]
    DC
    RRI
    2539.5
    [m]
    SWC
    OD
    2546.0
    [m]
    DC
    RRI
    2555.0
    [m]
    DC
    RRI
    2576.0
    [m]
    DC
    RRI
    2588.0
    [m]
    DC
    RRI
    2602.5
    [m]
    SWC
    OD
    2623.0
    [m]
    SWC
    OD
    2636.0
    [m]
    DC
    RRI
    2654.0
    [m]
    SWC
    OD
    2661.0
    [m]
    SWC
    OD
    2684.0
    [m]
    DC
    RRI
    2692.0
    [m]
    SWC
    OD
    2696.0
    [m]
    DC
    RRI
    2715.5
    [m]
    SWC
    OD
    2722.3
    [m]
    SWC
    OD
    2741.5
    [m]
    SWC
    OD
    2749.1
    [m]
    SWC
    OD
    2756.0
    [m]
    DC
    RRI
    2768.0
    [m]
    DC
    RRI
    2790.0
    [m]
    SWC
    OD
    2801.0
    [m]
    DC
    RRI
    2815.5
    [m]
    SWC
    OD
    2828.0
    [m]
    DC
    RRI
    2843.0
    [m]
    DC
    RRI
    2876.0
    [m]
    DC
    RRI
    2894.0
    [m]
    DC
    RRI
    2900.0
    [m]
    SWC
    OD
    2917.0
    [m]
    SWC
    OD
    2933.0
    [m]
    DC
    RRI
    2943.0
    [m]
    SWC
    OD
    2948.0
    [m]
    DC
    RRI
    2966.0
    [m]
    DC
    RRI
    2981.0
    [m]
    DC
    RRI
    2996.0
    [m]
    DC
    RRI
    3006.0
    [m]
    SWC
    OD
    3026.0
    [m]
    DC
    RRI
    3038.0
    [m]
    DC
    RRI
    3050.0
    [m]
    SWC
    OD
    3071.0
    [m]
    DC
    RRI
    3088.0
    [m]
    SWC
    OD
    3092.0
    [m]
    DC
    RRI
    3102.0
    [m]
    SWC
    OD
    3108.4
    [m]
    C
    RRI
    3111.0
    [m]
    C
    RRI
    3114.0
    [m]
    C
    RRI
    3118.0
    [m]
    C
    RRI
    3121.5
    [m]
    C
    RRI
    3126.0
    [m]
    C
    RRI
    3128.0
    [m]
    C
    RRI
    3132.0
    [m]
    C
    RRI
    3136.3
    [m]
    C
    RRI
    3146.0
    [m]
    DC
    RRI
    3158.0
    [m]
    SWC
    OD
    3176.0
    [m]
    DC
    RRI
    3187.2
    [m]
    SWC
    OD
    3189.0
    [m]
    SWC
    OD
    3200.0
    [m]
    DC
    RRI
    3212.0
    [m]
    DC
    RRI
    3215.0
    [m]
    SWC
    OD
    3230.0
    [m]
    DC
    RRI
    3259.0
    [m]
    SWC
    OD
    3260.0
    [m]
    DC
    RRI
    3280.0
    [m]
    SWC
    OD
    3300.0
    [m]
    SWC
    OD
    3308.0
    [m]
    DC
    RRI
    3323.0
    [m]
    DC
    RRI
    3324.0
    [m]
    SWC
    OD
    3337.0
    [m]
    SWC
    OD
    3353.0
    [m]
    SWC
    OD
    3371.0
    [m]
    DC
    RRI
    3382.0
    [m]
    SWC
    OD
    3408.0
    [m]
    SWC
    OD
    3419.0
    [m]
    SWC
    OD
    3449.0
    [m]
    SWC
    OD
    3453.0
    [m]
    SWC
    OD
    3461.0
    [m]
    DC
    RRI
    3469.2
    [m]
    SWC
    OD
    3476.0
    [m]
    DC
    RRI
    3483.0
    [m]
    SWC
    OD
    3491.0
    [m]
    DC
    RRI
    3505.0
    [m]
    SWC
    OD
    3518.0
    [m]
    DC
    RRI
    3533.0
    [m]
    DC
    RRI
    3534.0
    [m]
    SWC
    OD
    3552.0
    [m]
    DC
    RRI
    3564.0
    [m]
    SWC
    OD
    3579.0
    [m]
    SWC
    OD
    3592.3
    [m]
    SWC
    OD
    3604.0
    [m]
    SWC
    OD
    3615.0
    [m]
    DC
    RRI
    3624.0
    [m]
    SWC
    OD
    3644.0
    [m]
    DC
    RRI
    3647.5
    [m]
    C
    RRI
    3656.0
    [m]
    C
    RRI
    3665.0
    [m]
    SWC
    OD
    3686.0
    [m]
    DC
    RRI
    3699.0
    [m]
    DC
    RRI
    3716.0
    [m]
    DC
    RRI
    3734.5
    [m]
    SWC
    OD
    3745.5
    [m]
    C
    RRI
    3749.0
    [m]
    C
    RRI
    3750.0
    [m]
    C
    RRI
    3751.5
    [m]
    SWC
    OD
    3760.0
    [m]
    DC
    RRI
    3770.0
    [m]
    DC
    RRI
    3791.0
    [m]
    DC
    RRI
    3794.0
    [m]
    SWC
    OD
    3806.0
    [m]
    DC
    RRI
    3821.0
    [m]
    DC
    RRI
    3833.0
    [m]
    DC
    RRI
    3854.0
    [m]
    SWC
    OD
    3863.0
    [m]
    DC
    RRI
    3874.0
    [m]
    SWC
    OD
    3881.0
    [m]
    DC
    RRI
    3898.0
    [m]
    DC
    RRI
    3909.0
    [m]
    SWC
    OD
    3923.0
    [m]
    DC
    RRI
    3949.5
    [m]
    SWC
    OD
    3960.0
    [m]
    DC
    RRI
    3979.0
    [m]
    SWC
    OD
    3990.0
    [m]
    SWC
    OD
    4009.0
    [m]
    SWC
    OD
    4026.0
    [m]
    C
    RRI
    4074.0
    [m]
    SWC
    OD
    4124.0
    [m]
    SWC
    OD
    4133.0
    [m]
    DC
    RRI
    4142.0
    [m]
    DC
    RRI
    4142.0
    [m]
    SWC
    OD
    4197.5
    [m]
    SWC
    OD
    4217.5
    [m]
    SWC
    OD
    4231.3
    [m]
    SWC
    OD
    4238.0
    [m]
    SWC
    OD
    4245.0
    [m]
    SWC
    OD
    4247.1
    [m]
    SWC
    OD
    4252.0
    [m]
    SWC
    OD
    4262.5
    [m]
    SWC
    OD
    4276.0
    [m]
    SWC
    OD
    4287.5
    [m]
    SWC
    OD
    4296.0
    [m]
    SWC
    OD
    4317.0
    [m]
    SWC
    OD

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.62

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    1.06
    pdf
    2.30
    pdf
    0.37
    pdf
    1.03

  • 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
    3.51
    pdf
    46.50

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL GR
    1550
    1980
    CST GR
    2266
    4142
    DIR
    1264
    1343
    DPR PWD
    1341
    1641
    DPR PWD
    1844
    4317
    DSI LDT NGT
    1908
    2220
    FMI GR
    2275
    4231
    MDT GR
    2287
    3193
    MDT GR
    3102
    4215
    PEX HALS DSI NGT
    2243
    3320
    PEX HALS DSI NGT
    3200
    4229
    PEX HALS DSI NGT
    3700
    4315
    PWD - GR RES DIR
    1660
    1924
    RFT GR
    2288
    2290

  • 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
    1340.0
    36
    1343.0
    0.00
    LOT
    SURF.COND.
    20
    1431.0
    26
    1445.0
    1.15
    LOT
    LINER
    16
    1908.0
    17 1/2
    1911.0
    1.26
    LOT
    LINER
    9 5/8
    2246.0
    14 3/4
    2250.0
    1.36
    LOT
    OPEN HOLE
    4317.0
    8 1/2
    4317.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    1264
    1.02
    spud mud
    1341
    1.05
    spud mud
    1641
    1.13
    6.0
    4.5
    barasilc
    1907
    1.11
    6.0
    4.0
    barasilc
    1933
    1.20
    22.0
    9.5
    sea water
    2246
    1.26
    27.5
    12.0
    barasilc
    4317
    1.26
    27.5
    12.0
    barasilc

  • 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
    0.29