Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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26.11.2024 - 01:27
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6305/8-1

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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.
    6305/8-1
    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).
    APPRAISAL
    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
    Field
    Name of the field the wellbore is related to.
    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.
    6305/8-1
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    innline 2288-crossline 4182 NH 9602
    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.
    978-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.
    58
    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,
    13.07.2000
    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.
    08.09.2000
    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.
    08.09.2000
    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.
    08.09.2002
    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.
    18.12.2002
    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.
    APPRAISAL
    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/GAS
    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
    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.
    PALEOCENE
    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.
    EGGA FM (INFORMAL)
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    25.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    837.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3175.0
    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).
    3174.8
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    1.7
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    90
    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.
    NISE FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    63° 28' 34.84'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    5° 24' 14.59'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7041085.11
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    619767.97
    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.
    4109

  • Wellbore history
    General
    Well 6305/8-1 was a joint appraisal well on the Ormen Lange discovery between licences 208, 209 and 250. It was committed to test the reservoir potential of the Tertiary sequence in licence 250. The main target was a sand ("Egga Member") in the Tang Formation. The exploration objectives of the well were to appraise the 6305/5-1 Ormen Lange gas discovery, to test the hydrocarbon potential, type of hydrocarbons and seal in a secondary target Miocene Channel feature, and to improve biostratigraphic control in the area. In addition, the well was designed to provide a variety of information required for development planning of the Ormen Lange discovery.
    Operations and results
    Appraisal well was spudded with the semi-submersible installation Scarabeo 5 on 13 July 2000 and drilled to a total depth of 3175 m in the Late Cretaceous (Campanian & Late Santonian) Nise Formation. No problems were experienced drilling through the ooze sequence. The well was drilled with bentonite spud mud down to 942 m. A water based mud type based on NaCl brine with glycol additives was used from 942 m to TD. No potential reservoir sandstone was encountered in the Miocene channel sequence, penetrated at 1653 m. The Egga reservoir sandstone was penetrated approximately 20 m higher than prognosed at 2898 m. A gas column of approximately 20 m was penetrated in the well. Below the gas was a thin 2-5 m oil leg, which was not prognosed. The oil was confirmed by MDT sampling, and geochemical analyses indicated that the oil is sourced from a comparatively immature source rock. The gas/oil/water contact was found at 2921.5 m. The upper part of the Egga Member, from 2900 m to 2935 m, was a loose sand interbedded with thin claystone beds. The lower part of the Egga reservoir unit consisted of a more massive sand sequence down to approx. 2950 m. The Jorsalfare Formation consists of interbedded sands and mudstones. Good quality water, oil and gas samples were collected in the reservoir. The entire reservoir in the well was cored: Five cores were cut through the Våle (Egga Member) and Jorsalfare Formation sandstones from 2895 m to 2989 m. Core recovery was excellent (92 %- 100 %). Several MDT samples containing oil and gas were recovered from sampling points at 2923.5 m, 2922 m, 2919.6 m, 2914 m and 2908.2 m. MDT water samples were recovered from sampling points 2980.5 m, 2945 m and 2942.6 m. The well was plugged and abandoned as an oil and gas appraisal well on 8 September 2000.
    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]
    1560.00
    3175.00

  • 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
    2895.0
    2914.5
    [m ]
    2
    2915.5
    2943.3
    [m ]
    3
    2943.3
    2958.9
    [m ]
    4
    2959.1
    2980.3
    [m ]
    5
    2981.0
    2987.7
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    90.7
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 2895-2899m
    Core photo at depth: 2899-2903m
    Core photo at depth: 2903-2907m
    Core photo at depth: 2907-2911m
    Core photo at depth: 2911-2914m
    2895-2899m
    2899-2903m
    2903-2907m
    2907-2911m
    2911-2914m
    Core photo at depth: 2915-2919m
    Core photo at depth: 2929-2923m
    Core photo at depth: 2923-2927m
    Core photo at depth: 2927-2931m
    Core photo at depth: 2931-2935m
    2915-2919m
    2929-2923m
    2923-2927m
    2927-2931m
    2931-2935m
    Core photo at depth: 2935-2939m
    Core photo at depth: 2939-2943m
    Core photo at depth: 2943-2944m
    Core photo at depth: 2943-2947m
    Core photo at depth: 2981-2985m
    2935-2939m
    2939-2943m
    2943-2944m
    2943-2947m
    2981-2985m
    Core photo at depth: 2947-2951m
    Core photo at depth: 2951-2955m
    Core photo at depth: 2955-2959m
    Core photo at depth: 2959-2963m
    Core photo at depth: 2963-2967m
    2947-2951m
    2951-2955m
    2955-2959m
    2959-2963m
    2963-2967m
    Core photo at depth: 2967-2971m
    Core photo at depth: 2971-2975m
    Core photo at depth: 2975-2979m
    Core photo at depth: 2979-2980m
    Core photo at depth: 2985-2988m
    2967-2971m
    2971-2975m
    2975-2979m
    2979-2980m
    2985-2988m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1562.5
    [m]
    SWC
    RRI
    1585.0
    [m]
    DC
    RRI
    1595.0
    [m]
    DC
    RRI
    1605.0
    [m]
    SWC
    RRI
    1633.0
    [m]
    SWC
    RRI
    1655.0
    [m]
    SWC
    RRI
    1665.0
    [m]
    SWC
    RRI
    1712.0
    [m]
    SWC
    RRI
    1735.0
    [m]
    DC
    RRI
    1750.0
    [m]
    DC
    RRI
    1782.5
    [m]
    SWC
    RRI
    1800.0
    [m]
    SWC
    RRI
    1820.0
    [m]
    SWC
    RRI
    1850.0
    [m]
    DC
    RRI
    1870.0
    [m]
    DC
    RRI
    1890.0
    [m]
    DC
    RRI
    1910.0
    [m]
    DC
    RRI
    1930.0
    [m]
    DC
    RRI
    1950.0
    [m]
    DC
    RRI
    1970.0
    [m]
    DC
    RRI
    1990.0
    [m]
    DC
    RRI
    2010.0
    [m]
    DC
    RRI
    2030.0
    [m]
    DC
    RRI
    2050.0
    [m]
    DC
    RRI
    2070.0
    [m]
    DC
    RRI
    2090.0
    [m]
    DC
    RRI
    2110.0
    [m]
    DC
    RRI
    2130.0
    [m]
    DC
    RRI
    2150.0
    [m]
    DC
    RRI
    2170.0
    [m]
    DC
    RRI
    2190.0
    [m]
    DC
    RRI
    2210.0
    [m]
    DC
    RRI
    2230.0
    [m]
    DC
    RRI
    2250.0
    [m]
    DC
    RRI
    2270.0
    [m]
    DC
    RRI
    2290.0
    [m]
    DC
    RRI
    2310.0
    [m]
    DC
    RRI
    2330.0
    [m]
    DC
    RRI
    2350.0
    [m]
    DC
    RRI
    2370.0
    [m]
    DC
    RRI
    2390.0
    [m]
    DC
    RRI
    2420.0
    [m]
    DC
    RRI
    2440.0
    [m]
    DC
    RRI
    2460.0
    [m]
    DC
    RRI
    2480.0
    [m]
    DC
    RRI
    2520.0
    [m]
    DC
    RRI
    2540.0
    [m]
    DC
    RRI
    2560.0
    [m]
    DC
    RRI
    2580.0
    [m]
    DC
    RRI
    2600.0
    [m]
    DC
    RRI
    2620.0
    [m]
    DC
    RRI
    2640.0
    [m]
    DC
    RRI
    2660.0
    [m]
    DC
    RRI
    2680.0
    [m]
    DC
    RRI
    2700.0
    [m]
    DC
    RRI
    2720.0
    [m]
    DC
    RRI
    2740.0
    [m]
    DC
    RRI
    2760.0
    [m]
    DC
    RRI
    2780.0
    [m]
    DC
    RRI
    2800.0
    [m]
    DC
    RRI
    2820.0
    [m]
    DC
    RRI
    2840.0
    [m]
    DC
    RRI
    2850.0
    [m]
    DC
    RRI
    2857.0
    [m]
    DC
    RRI
    2860.0
    [m]
    SWC
    RRI
    2862.0
    [m]
    DC
    RRI
    2871.0
    [m]
    DC
    RRI
    2877.0
    [m]
    DC
    RRI
    2880.0
    [m]
    DC
    RRI
    2883.0
    [m]
    DC
    RRI
    2886.0
    [m]
    DC
    RRI
    2889.0
    [m]
    DC
    RRI
    2895.0
    [m]
    DC
    RRI
    2895.1
    [m]
    C
    RRI
    2895.9
    [m]
    C
    RRI
    2896.8
    [m]
    C
    RRI
    2897.6
    [m]
    C
    RRI
    2899.1
    [m]
    C
    RRI
    2900.1
    [m]
    C
    RRI
    2901.2
    [m]
    C
    RRI
    2903.2
    [m]
    C
    RRI
    2903.9
    [m]
    C
    RRI
    2905.6
    [m]
    C
    RRI
    2908.7
    [m]
    C
    RRI
    2909.1
    [m]
    C
    RRI
    2910.9
    [m]
    C
    RRI
    2911.5
    [m]
    C
    RRI
    2912.5
    [m]
    C
    RRI
    2915.8
    [m]
    C
    RRI
    2916.9
    [m]
    C
    RRI
    2918.7
    [m]
    C
    RRI
    2920.4
    [m]
    C
    RRI
    2920.7
    [m]
    C
    RRI
    2921.8
    [m]
    C
    RRI
    2924.4
    [m]
    C
    RRI
    2930.9
    [m]
    C
    RRI
    2935.7
    [m]
    C
    RRI
    2949.7
    [m]
    C
    RRI
    2950.0
    [m]
    C
    RRI
    2951.2
    [m]
    C
    RRI
    2952.5
    [m]
    C
    RRI
    2955.4
    [m]
    C
    RRI
    2956.5
    [m]
    C
    RRI
    2958.8
    [m]
    C
    RRI
    2959.0
    [m]
    C
    RRI
    2959.6
    [m]
    C
    RRI
    2960.0
    [m]
    C
    RRI
    2961.0
    [m]
    C
    RRI
    2961.5
    [m]
    C
    RRI
    2962.0
    [m]
    C
    RRI
    2965.6
    [m]
    C
    RRI
    2967.0
    [m]
    C
    RRI
    2971.0
    [m]
    C
    RRI
    2972.7
    [m]
    C
    RRI
    2974.6
    [m]
    C
    RRI
    2978.3
    [m]
    C
    RRI
    2981.1
    [m]
    C
    RRI
    2982.0
    [m]
    DC
    RRI
    2983.8
    [m]
    C
    RRI
    2985.0
    [m]
    DC
    RRI
    2987.4
    [m]
    C
    RRI
    2991.0
    [m]
    DC
    RRI
    2997.0
    [m]
    DC
    RRI
    3000.0
    [m]
    DC
    RRI
    3003.0
    [m]
    DC
    RRI
    3006.0
    [m]
    DC
    RRI
    3009.0
    [m]
    DC
    RRI
    3012.0
    [m]
    DC
    RRI
    3015.0
    [m]
    DC
    RRI
    3051.0
    [m]
    DC
    RRI
    3072.0
    [m]
    DC
    RRI
    3090.0
    [m]
    DC
    RRI
    3111.0
    [m]
    DC
    RRI
    3132.0
    [m]
    DC
    RRI
    3150.0
    [m]
    DC
    RRI
    3165.0
    [m]
    DC
    RRI
    3168.0
    [m]
    DC
    RRI
    3171.0
    [m]
    DC
    RRI
    3175.0
    [m]
    DC
    RRI

  • 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
    MDT-1
    2942.00
    0.00
    WATER
    12.08.2000 - 00:00
    YES
    MDT
    2922.00
    0.00
    OIL
    29.08.2000 - 00:00
    YES

  • Lithostratigraphy
    Lithostratigraphy
    Top depth [mMD RKB]
    Lithostrat. unit
    862
    862
    1590
    1745
    1745
    2508
    2508
    2596
    2898
    2976
    2976
    3132

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.33

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    1.92
    pdf
    1.86
    pdf
    1.44
    pdf
    1.97
    pdf
    1.90
    pdf
    1.92
    pdf
    1.79
    pdf
    1.81

  • 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
    2.18
    .pdf
    1.03

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CMR ECS HNGS
    2880
    2926
    CMR-200
    2900
    3022
    DSI
    1750
    3172
    FMI HRLA HNGS
    2852
    3156
    MDT
    2908
    3010
    MSCT GR
    1562
    1820
    MSCT GR
    2860
    3030
    MWD - GR RES SON DIR
    915
    3053
    PEX HALS TLD HGNS
    2852
    3170
    PWX DSI
    862
    1848
    VSP
    900
    1770
    VSP
    2040
    3170

  • 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
    941.0
    36
    942.0
    0.00
    LOT
    INTERM.
    20
    1544.0
    26
    1550.0
    1.40
    LOT
    INTERM.
    9 5/8
    2852.0
    12 1/4
    2860.0
    1.66
    LOT
    OPEN HOLE
    3175.0
    8 1/2
    3175.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    867
    1.30
    WATER BASED
    890
    1.30
    WATER BASED
    942
    1.50
    WATER BASED
    942
    1.30
    WATER BASED
    2895
    1.30
    16.0
    WATER BASED
    2943
    1.30
    16.0
    WATER BASED
    2981
    1.30
    19.0
    WATER BASED
    2982
    1.30
    18.0
    WATER BASED
    2989
    1.30
    18.0
    WATER BASED
    3013
    1.30
    19.0
    WATER BASED
    3175
    1.30
    23.0
    WATER BASED

  • Thin sections at the Norwegian Offshore Directorate
    Thin sections at the Norwegian Offshore Directorate
    Depth
    Unit
    2927.82
    [m ]
    2985.46
    [m ]

  • 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