Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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23.07.2024 - 01:26
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6407/10-2

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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.
    6407/10-2
    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.
    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.
    6407/10-2
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    NH 8604-808 LINE 270 COLUMN 8604-1420
    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.
    633-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.
    52
    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,
    03.05.1990
    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.
    23.06.1990
    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.
    23.06.1992
    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.
    02.03.2004
    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.
    25.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    334.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3825.0
    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).
    3824.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    4.5
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    120
    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.
    TILJE FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    64° 13' 44.34'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    7° 16' 54.02'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7123832.87
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    416644.87
    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.
    1497
  • Wellbore history

    General
    Well 6407/10-2 was drilled on the B-II structure south-east of the Njord Field, and is characterized by a prominent hanging wall anticline and syncline off the Trøndelag Platform and shows little tectonic disturbance as seen on seismic sections. From tectonic model inferred in the area, the tectonic damage to the reservoir rocks was expected to be less than previously encountered in the A-Central and the A-North areas. Movements along the main fault during the Late Jurassic caused sedimentation of Triassic and / or Middle and Early Jurassic clastics of delta fan type. Source rock for B-II area was prognosed to be the mature part of the Spekk Formation. Possible shallow gas might be present some 30 - 40 m below sea level. One core would be taken in each of the Garn, Ile and Tilje formations. The main objectives for the well were to asses the reservoir quality and hydrocarbon potential of the Garn, Ile, and Tilje Formations and the Late Jurassic sequence; to obtain reservoir pressure; confirm the seismic and geological model; and to asses the presence of sands in the Early Cretaceous sequence.
    Prognosed TD was 3700 m in the upper part of the Tilje Formation, or alternatively 4040 m in Triassic rocks.
    Operations and results
    Wildcat well 6407/10-2 was spudded with the semi-submersible rig Vildkat Explorer on 3 May 1990 and drilled to TD at 3825 m in the Early Jurassic Tilje Formation sandstones. The well was drilled with seawater and hi-vis pills down to1070 m and with KCl/Polymer/Polyacrylamide mud system from 1070 m to TD. In the 17 1/2" section 1070 to 2188 m mud from a previous well was used, below 2188 m fresh mud was used. Apart from some difficulties during logging, drilling went on without any significant problems. No shallow gas was encountered in this well. Apart from 8 m Lysing sand at 2378 m there was no significant sand body development in the Cretaceous succession. The Garn Formation was not present in the well location. Hydrocarbons were absent in both the Ile- and Tilje formations. Weak to very weak shows were observed on claystones between 2660 m to 2720 m in the Lange Formation. Moderate to very weak shows were observed on claystones and sandstones throughout most of the Jurassic section. A total of 180 sidewall cores were attempted in three runs, and 104 were recovered. Two conventional cores were cut in the Ile- and Tilje formations. No fluid samples were taken. The well was permanently abandoned on 23 June 1990 as a dry well.
    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]
    1080.00
    3825.00
  • 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
    3446.0
    3457.2
    [m ]
    2
    3682.0
    3694.0
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    23.2
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES
  • Core photos

    Core photos
    Core photo at depth: 3442-3447m
    Core photo at depth: 3447-3452m
    Core photo at depth: 3452-3457m
    Core photo at depth: 3457-3686m
    Core photo at depth: 3686-3691m
    3442-3447m
    3447-3452m
    3452-3457m
    3457-3686m
    3686-3691m
    Core photo at depth: 3691-3693m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    3691-3693m
  • Palynological slides at the Norwegian Offshore Directorate

    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1080.0
    [m]
    DC
    STRAT
    1090.0
    [m]
    DC
    STRAT
    1110.0
    [m]
    DC
    STRAT
    1140.0
    [m]
    DC
    STRAT
    1170.0
    [m]
    DC
    STRAT
    1210.0
    [m]
    DC
    STRAT
    1250.0
    [m]
    DC
    STRAT
    1290.0
    [m]
    DC
    STRAT
    1330.0
    [m]
    DC
    STRAT
    1370.0
    [m]
    DC
    STRAT
    1400.0
    [m]
    DC
    STRAT
    1440.0
    [m]
    DC
    STRAT
    1480.0
    [m]
    DC
    STRAT
    1520.0
    [m]
    DC
    STRAT
    1560.0
    [m]
    DC
    STRAT
    1620.0
    [m]
    DC
    HYDRO
    1630.0
    [m]
    DC
    HYDRO
    1640.0
    [m]
    DC
    STRAT
    1660.0
    [m]
    DC
    HYDRO
    1680.0
    [m]
    DC
    STRAT
    1720.0
    [m]
    DC
    STRAT
    1760.0
    [m]
    DC
    STRAT
    1800.0
    [m]
    DC
    STRAT
    1840.0
    [m]
    DC
    STRAT
    1860.0
    [m]
    DC
    HYDRO
    1880.0
    [m]
    DC
    STRAT
    1890.0
    [m]
    DC
    HYDRO
    1900.0
    [m]
    DC
    HYDRO
    1910.0
    [m]
    DC
    HYDRO
    1920.0
    [m]
    DC
    STRAT
    1960.0
    [m]
    DC
    STRAT
    2000.0
    [m]
    DC
    STRAT
    2040.0
    [m]
    DC
    STRAT
    2080.0
    [m]
    DC
    STRAT
    2120.0
    [m]
    DC
    STRAT
    2160.0
    [m]
    DC
    STRAT
    2200.0
    [m]
    DC
    STRAT
    2240.0
    [m]
    DC
    STRAT
    2280.0
    [m]
    DC
    STRAT
    2410.0
    [m]
    DC
    STRAT
    2430.0
    [m]
    DC
    STRAT
    2445.0
    [m]
    DC
    STRAT
    2455.0
    [m]
    DC
    STRAT
    2465.0
    [m]
    DC
    STRAT
    2495.0
    [m]
    DC
    STRAT
    2505.0
    [m]
    DC
    STRAT
    2515.0
    [m]
    DC
    STRAT
    2525.0
    [m]
    DC
    STRAT
    2555.0
    [m]
    DC
    STRAT
    2585.0
    [m]
    DC
    STRAT
    2595.0
    [m]
    DC
    STRAT
    2605.0
    [m]
    DC
    STRAT
    2615.0
    [m]
    DC
    STRAT
    2635.0
    [m]
    DC
    STRAT
    2675.0
    [m]
    DC
    STRAT
    2685.0
    [m]
    DC
    STRAT
    2695.0
    [m]
    DC
    STRAT
    2705.0
    [m]
    DC
    STRAT
    2715.0
    [m]
    DC
    STRAT
    2735.0
    [m]
    DC
    STRAT
    2745.0
    [m]
    DC
    STRAT
    2755.0
    [m]
    DC
    STRAT
    2765.0
    [m]
    DC
    STRAT
    2775.0
    [m]
    DC
    STRAT
    2795.0
    [m]
    DC
    STRAT
    2805.0
    [m]
    DC
    STRAT
    2815.0
    [m]
    DC
    STRAT
    2822.0
    [m]
    DC
    PETROSTR
    2827.0
    [m]
    DC
    PETROS
    2832.0
    [m]
    DC
    PETROS
    2837.0
    [m]
    DC
    PETROS
    2842.0
    [m]
    DC
    PETROS
    2847.0
    [m]
    DC
    PETROS
    2852.0
    [m]
    DC
    PETROS
    2855.0
    [m]
    DC
    PETROS
    2855.0
    [m]
    DC
    STRAT
    2860.0
    [m]
    DC
    PETROSTR
    2865.0
    [m]
    DC
    PETROS
    2870.0
    [m]
    DC
    PETROS
    2875.0
    [m]
    DC
    PETROS
    2880.0
    [m]
    DC
    PETROS
    2885.0
    [m]
    DC
    PETROS
    2885.0
    [m]
    DC
    STRAT
    2890.0
    [m]
    DC
    PETROS
    2895.0
    [m]
    DC
    PETROS
    2895.0
    [m]
    DC
    STRAT
    2900.0
    [m]
    DC
    PETROSTR
    2905.0
    [m]
    DC
    PETROS
    2910.0
    [m]
    DC
    PETROS
    2915.0
    [m]
    DC
    STRAT
    2925.0
    [m]
    DC
    STRAT
    2930.0
    [m]
    DC
    STRAT
    2930.0
    [m]
    DC
    PETROSTR
    2935.0
    [m]
    DC
    STRAT
    2945.0
    [m]
    DC
    STRAT
    2947.0
    [m]
    DC
    PETROSTR
    2955.0
    [m]
    DC
    STRAT
    2965.0
    [m]
    DC
    STRAT
    2965.0
    [m]
    DC
    PETROSTR
    2975.0
    [m]
    DC
    STRAT
    2985.0
    [m]
    DC
    STRAT
    2985.0
    [m]
    DC
    PETROSTR
    3015.0
    [m]
    DC
    STRAT
    3025.0
    [m]
    DC
    STRAT
    3035.0
    [m]
    DC
    STRAT
    3045.0
    [m]
    DC
    STRAT
    3055.0
    [m]
    DC
    STRAT
    3085.0
    [m]
    DC
    STRAT
    3105.0
    [m]
    DC
    STRAT
    3140.0
    [m]
    DC
    STRAT
    3150.0
    [m]
    DC
    STRAT
    3160.0
    [m]
    DC
    STRAT
    3180.0
    [m]
    DC
    STRAT
    3200.0
    [m]
    DC
    STRAT
    3220.0
    [m]
    DC
    STRAT
    3250.0
    [m]
    DC
    STRAT
    3280.0
    [m]
    DC
    STRAT
    3290.0
    [m]
    DC
    STRAT
    3300.0
    [m]
    DC
    STRAT
    3310.0
    [m]
    DC
    STRAT
    3340.0
    [m]
    DC
    STRAT
    3360.0
    [m]
    DC
    HYDRO
    3370.0
    [m]
    DC
    STRAT
    3400.0
    [m]
    DC
    STRAT
    3430.0
    [m]
    DC
    STRAT
    3470.0
    [m]
    DC
    STRAT
    3480.0
    [m]
    DC
    STRAT
    3500.0
    [m]
    DC
    STRAT
    3510.0
    [m]
    DC
    STRAT
    3520.0
    [m]
    DC
    STRAT
    3530.0
    [m]
    DC
    STRAT
    3540.0
    [m]
    DC
    STRAT
    3550.0
    [m]
    DC
    STRAT
    3560.0
    [m]
    DC
    STRAT
    3590.0
    [m]
    DC
    STRAT
    3610.0
    [m]
    DC
    STRAT
    3640.0
    [m]
    DC
    STRAT
    3660.0
    [m]
    DC
    STRAT
    3670.0
    [m]
    DC
    STRAT
    3700.0
    [m]
    DC
    STRAT
    3710.0
    [m]
    DC
    STRAT
    3720.0
    [m]
    DC
    STRAT
    3750.0
    [m]
    DC
    STRAT
    3770.0
    [m]
    DC
    STRAT
    3780.0
    [m]
    DC
    STRAT
    3800.0
    [m]
    DC
    STRAT
    3825.0
    [m]
    DC
    HYDRO
  • Lithostratigraphy

  • Composite logs

    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.53
  • Geochemical information

    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.91
  • 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
    19.10
  • Logs

    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL VDL GR
    1700
    2163
    CNL NGL AMS
    2163
    3828
    CST GR
    2230
    3010
    CST GR
    2230
    3793
    CST GR
    3025
    3813
    DIL LDL SP GR
    2163
    3828
    DIL LSS LDL SP GR
    1054
    2185
    FMS GR AMS
    2163
    3828
    LSS GR
    0
    0
    LSS GR
    2163
    3250
    MWD - GR RES DIR
    359
    3825
    RFT HP AMS
    2383
    3779
    SDT GR AMS
    3030
    3826
    VSP
    2220
    3810
  • 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
    445.0
    36
    447.0
    0.00
    LOT
    INTERM.
    20
    1056.0
    26
    1070.0
    1.95
    LOT
    INTERM.
    13 3/8
    2164.0
    17 1/2
    2188.0
    1.70
    LOT
    OPEN HOLE
    3825.0
    12 1/4
    3825.0
    0.00
    LOT
  • Drilling mud

    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    397
    1.07
    WATER BASED
    03.05.1990
    406
    1.07
    WATER BASED
    04.05.1990
    443
    1.07
    WATER BASED
    10.05.1990
    447
    1.07
    WATER BASED
    10.05.1990
    448
    1.07
    WATER BASED
    10.05.1990
    808
    1.10
    WATER BASED
    10.05.1990
    1070
    1.07
    WATER BASED
    10.05.1990
    1070
    1.07
    WATER BASED
    14.05.1990
    1070
    1.10
    WATER BASED
    10.05.1990
    1070
    1.07
    WATER BASED
    14.05.1990
    1177
    1.45
    11.0
    8.0
    WATER BASED
    14.05.1990
    1364
    1.60
    19.0
    8.0
    WATER BASED
    14.05.1990
    1529
    1.60
    25.0
    8.0
    WATER BASED
    15.05.1990
    1656
    1.60
    24.0
    13.0
    WATER BASED
    16.05.1990
    1969
    1.59
    26.0
    10.0
    WATER BASED
    21.05.1990
    2040
    1.32
    17.0
    10.0
    WATER BASED
    22.06.1990
    2119
    1.60
    30.0
    13.0
    WATER BASED
    21.05.1990
    2168
    1.60
    25.0
    11.0
    WATER BASED
    21.05.1990
    2188
    1.59
    32.0
    12.0
    WATER BASED
    21.05.1990
    2188
    1.59
    31.0
    9.0
    WATER BASED
    21.05.1990
    2191
    1.38
    27.0
    10.0
    WATER BASED
    22.05.1990
    2435
    1.38
    25.0
    10.0
    WATER BASED
    23.05.1990
    2590
    1.38
    23.0
    11.0
    WATER BASED
    25.05.1990
    2656
    1.39
    18.0
    10.0
    WATER BASED
    25.05.1990
    2768
    1.38
    26.0
    8.0
    WATER BASED
    28.05.1990
    2853
    1.38
    21.0
    10.0
    WATER BASED
    28.05.1990
    2887
    1.38
    17.0
    10.0
    WATER BASED
    28.05.1990
    2960
    1.38
    28.0
    10.0
    WATER BASED
    29.05.1990
    3033
    1.38
    21.0
    7.0
    WATER BASED
    30.05.1990
    3164
    1.38
    27.0
    7.0
    WATER BASED
    31.05.1990
    3202
    1.38
    21.0
    10.0
    WATER BASED
    05.06.1990
    3252
    1.38
    20.0
    10.0
    WATER BASED
    05.06.1990
    3305
    1.38
    25.0
    12.0
    WATER BASED
    05.06.1990
    3357
    1.38
    24.0
    10.0
    WATER BASED
    05.06.1990
    3370
    1.32
    17.0
    10.0
    WATER BASED
    21.06.1990
    3411
    1.38
    22.0
    11.0
    WATER BASED
    05.06.1990
    3442
    1.38
    14.0
    10.0
    WATER BASED
    06.06.1990
    3458
    1.38
    23.0
    13.0
    WATER BASED
    07.06.1990
    3509
    1.38
    20.0
    10.0
    WATER BASED
    08.06.1990
    3553
    1.38
    20.0
    10.0
    WATER BASED
    11.06.1990
    3587
    1.38
    22.0
    12.0
    WATER BASED
    11.06.1990
    3641
    1.38
    20.0
    13.0
    WATER BASED
    11.06.1990
    3664
    1.38
    22.0
    12.0
    WATER BASED
    12.06.1990
    3682
    1.38
    22.0
    12.0
    WATER BASED
    13.06.1990
    3700
    1.38
    20.0
    12.0
    WATER BASED
    14.06.1990
    3806
    1.38
    19.0
    14.0
    WATER BASED
    14.06.1990
    3825
    1.38
    19.0
    14.0
    WATER BASED
    18.06.1990
    3825
    1.32
    17.0
    10.0
    WATER BASED
    18.06.1990
    3825
    1.38
    19.0
    14.0
    WATER BASED
    18.06.1990
    3825
    1.32
    17.0
    10.0
    WATER BASED
    19.06.1990
    3825
    1.32
    17.0
    10.0
    WATER BASED
    20.06.1990
  • 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