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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34/10-17

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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.
    34/10-17
    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
    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.
    34/10-17
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    8213 - 177 SP 158
    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.
    364-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.
    137
    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,
    22.02.1983
    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.
    08.07.1983
    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.
    08.07.1985
    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.
    30.09.2011
    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.
    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.
    YES
    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.
    MIDDLE JURASSIC
    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.
    BRENT GP
    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.
    135.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3466.0
    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).
    3460.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    10
    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.
    STATFJORD GP
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    61° 3' 58.93'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 0' 50.78'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6770741.25
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    446787.09
    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.
    5

  • Wellbore history
    General
    Well 34/10-17 was the first well drilled on the Beta structure in the SE segment of block 34/10, south-west of the Alpha-structure, which contained the Gullfaks Sør Field. The primary objective of the well was to evaluate possible hydrocarbon accumulations in the Middle Jurassic Brent sandstones. The secondary objectives were the Early Jurassic Dunlin and Statfjord sandstones.
    Operations and results
    Wildcat well 34/10-17 was spudded with the semi-submersible installation Deepsea Bergen on 22 February 1983 and drilled to TD at 3466 m in the Early Jurassic Statfjord Formation. The well was drilled down to 2687 m without special drilling problems. At 2687 m a heavy flow was observed after a drilling break. The well was shut in, and due to a plugged cement hose and kill line failsafe valve, about 200 hours were used to circulate out the influx, stabilize, clean up and condition the hole. Further technical failure and tight hole caused extensive time logging the 6" section, and the logging programme was reduced. The well was drilled with Seawater/gel spud mud down to 668 m and with seawater/gel/Lignosulphonate mud from 668 m to TD.
    The Brent Group was encountered at 2685 m with hydrocarbon bearing sandstones in the Tarbert and Ness Formations. FMT pressures indicated a gas/oil contact at ca 2862 m, and an oil/water contact at ca 2914 m in the lower part of the Ness Formation. The logs indicated a total oil and gas net pay of 122.5 m with average porosity 22.5% and average water saturation 27%. Also the underlying water bearing Etive and Rannoch Formations of the Brent Group had good reservoir quality sandstones. The Dunlin and Statfjord sandstones were water bearing. Shows were recorded on cores down to 2947.5 m in the Rannoch Formation, and a geochemical core extract from 2923 m showed a chromatographic fingerprint no different from core extracts taken in the oil-zone. Otherwise no significant oil shows were seen in the well outside of the oil-bearing reservoir.
    A total of 16 cores were cut continuously through the Brent reservoir section down to ca middle of the Rannoch Formation. The core-log depth match was generally good, but with minor deviations due to expansion of the cores after they were landed. The FMT tool was run for pressure samples in the Brent and Dunlin Group and in the Statfjord Formation. Segregated fluid samples were taken in the Brent Group at 2697 m (gas and condensate) and at 2889 m (oil).
    The well was permanently abandoned on 8 July 1983 as an oil and gas discovery.
    Testing
    The well was tested from four zones in the Brent sand. One DST produced water, the other produced hydrocarbons.
    DST 1 tested the interval 2934 to 2944 m and produced only water at a rate of 1024 Sm3/day through a 40/64" choke in the main flow. Maximum down hole temperature recorded in the test was 108.1 deg C.
    DST 2 tested the interval 2880 to 2890 m and produced 545 Sm3 oil and 134000 Sm3 gas/day through a 28/64" choke in the main flow. The GOR was 246 Sm3/Sm3, the oil density was 0.85 g/cm3, and the gas gravity was 0.74 (air = 1) with ca 1% CO2 and 1 ppm H2S. Maximum temperature recorded in the test was 106.0 deg C.
    DST 3 tested the interval 2835 to 2845 m and produced 452 Sm3 condensate and 364000 Sm3 gas/day through a 32/64" choke in the third flow period. The GCR was 805 Sm3/Sm3, the condensate density was 0.78 g/cm3, and the gas gravity was 0.72 (air = 1) with trace CO2 and no detectable H2S. A somewhat higher oil rate and lower GOR was recorded on a 48/64" choke in the second flow period. Maximum temperature recorded in the test was 104.3 deg C.
    DST 4 tested multiple intervals from 2754 to 2790.5 m and produced 320 Sm3 condensate and 428000 Sm3 gas/day through a 32/64" choke in the third flow. The GCR was 1338 Sm3/Sm3, the condensate density was 0.76 g/cm3, and the gas gravity was 0.71 (air = 1) with ca 1% CO2 and 0.6 ppm H2S. Maximum temperature recorded in the test was 101.2 deg C.

  • 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]
    230.00
    3465.00

  • 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
    2681.3
    2699.3
    [m ]
    2
    2700.1
    2718.1
    [m ]
    3
    2718.0
    2736.4
    [m ]
    4
    2736.0
    2754.0
    [m ]
    5
    2754.0
    2771.3
    [m ]
    6
    2772.0
    2790.0
    [m ]
    7
    2790.0
    2808.5
    [m ]
    8
    2808.0
    2826.2
    [m ]
    9
    2826.0
    2840.3
    [m ]
    10
    2840.0
    2858.0
    [m ]
    11
    2858.0
    2875.7
    [m ]
    12
    2876.0
    2894.3
    [m ]
    13
    2894.0
    2909.7
    [m ]
    14
    2912.0
    2930.0
    [m ]
    15
    2930.0
    2948.3
    [m ]
    16
    2948.0
    2965.8
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    282.5
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 2681-2688m
    Core photo at depth: 2688-2694m
    Core photo at depth: 2695-2699m
    Core photo at depth: 2700-2707m
    Core photo at depth: 2707-2714m
    2681-2688m
    2688-2694m
    2695-2699m
    2700-2707m
    2707-2714m
    Core photo at depth: 2714-2718m
    Core photo at depth: 2718-2725m
    Core photo at depth: 2725-2732m
    Core photo at depth: 2732-2736m
    Core photo at depth: 2736-2743m
    2714-2718m
    2718-2725m
    2725-2732m
    2732-2736m
    2736-2743m
    Core photo at depth: 2743-2750m
    Core photo at depth: 2750-2754m
    Core photo at depth: 2754-2761m
    Core photo at depth: 2761-2767m
    Core photo at depth: 2768-2771m
    2743-2750m
    2750-2754m
    2754-2761m
    2761-2767m
    2768-2771m
    Core photo at depth: 2772-2779m
    Core photo at depth: 2779-2786m
    Core photo at depth: 2786-2790m
    Core photo at depth: 2790-2797m
    Core photo at depth: 2797-2804m
    2772-2779m
    2779-2786m
    2786-2790m
    2790-2797m
    2797-2804m
    Core photo at depth: 2804-2808m
    Core photo at depth: 2808-2815m
    Core photo at depth: 2815-2822m
    Core photo at depth: 2822-2826m
    Core photo at depth: 2826-2833m
    2804-2808m
    2808-2815m
    2815-2822m
    2822-2826m
    2826-2833m
    Core photo at depth: 2833-2840m
    Core photo at depth: 2840-2840m
    Core photo at depth: 2840-2847m
    Core photo at depth: 2847-2854m
    Core photo at depth: 2854-2858m
    2833-2840m
    2840-2840m
    2840-2847m
    2847-2854m
    2854-2858m
    Core photo at depth: 2858-2865m
    Core photo at depth: 2858-2885m
    Core photo at depth: 2865-2872m
    Core photo at depth: 2872-2875m
    Core photo at depth: 2876-2883m
    2858-2865m
    2858-2885m
    2865-2872m
    2872-2875m
    2876-2883m
    Core photo at depth: 2883-2890m
    Core photo at depth: 2890-2894m
    Core photo at depth: 2894-2900m
    Core photo at depth: 2901-2907m
    Core photo at depth: 2908-2909m
    2883-2890m
    2890-2894m
    2894-2900m
    2901-2907m
    2908-2909m
    Core photo at depth: 2912-2919m
    Core photo at depth: 2919-2926m
    Core photo at depth: 2926-2930m
    Core photo at depth: 2930-2937m
    Core photo at depth: 2937-2944m
    2912-2919m
    2919-2926m
    2926-2930m
    2930-2937m
    2937-2944m
    Core photo at depth: 2944-2948m
    Core photo at depth: 2948-2955m
    Core photo at depth: 2955-2962m
    Core photo at depth: 2962-2965m
    Core photo at depth:  
    2944-2948m
    2948-2955m
    2955-2962m
    2962-2965m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    2681.0
    [m]
    C
    RRI
    2682.0
    [m]
    C
    RRI
    2683.0
    [m]
    C
    RRI
    2689.0
    [m]
    C
    RRI
    2690.0
    [m]
    C
    RRI
    2691.0
    [m]
    C
    RRI
    2692.0
    [m]
    C
    RRI
    2693.0
    [m]
    C
    RRI
    2700.0
    [m]
    C
    RRI
    2704.0
    [m]
    C
    RRI
    2712.0
    [m]
    C
    RRI
    2717.0
    [m]
    C
    RRI
    2718.0
    [m]
    C
    RRI
    2723.0
    [m]
    C
    RRI
    2724.0
    [m]
    C
    RRI
    2728.0
    [m]
    C
    RRI
    2733.0
    [m]
    C
    RRI
    2736.0
    [m]
    C
    RRI
    2737.0
    [m]
    C
    RRI
    2741.0
    [m]
    C
    RRI
    2744.0
    [m]
    C
    RRI
    2747.0
    [m]
    C
    RRI
    2750.0
    [m]
    C
    RRI
    2753.0
    [m]
    C
    RRI
    2756.0
    [m]
    C
    RRI
    2758.0
    [m]
    C
    RRI
    2761.0
    [m]
    C
    RRI
    2764.0
    [m]
    C
    RRI
    2766.0
    [m]
    C
    RRI
    2771.0
    [m]
    C
    RRI
    2772.0
    [m]
    C
    RRI
    2776.0
    [m]
    C
    RRI
    2779.0
    [m]
    C
    RRI
    2784.0
    [m]
    C
    RRI
    2791.0
    [m]
    C
    RRI
    2794.0
    [m]
    C
    RRI
    2796.0
    [m]
    C
    RRI
    2800.0
    [m]
    C
    RRI
    2803.0
    [m]
    C
    RRI
    2806.0
    [m]
    C
    RRI
    2808.0
    [m]
    C
    RRI
    2810.0
    [m]
    C
    RRI
    2812.0
    [m]
    C
    RRI
    2815.0
    [m]
    C
    RRI
    2823.0
    [m]
    C
    RRI
    2825.0
    [m]
    C
    RRI
    2827.0
    [m]
    C
    RRI
    2829.0
    [m]
    C
    RRI
    2831.0
    [m]
    C
    RRI
    2833.0
    [m]
    C
    RRI
    2842.0
    [m]
    C
    RRI
    2848.0
    [m]
    C
    RRI
    2853.0
    [m]
    C
    RRI
    2855.0
    [m]
    C
    RRI
    2859.0
    [m]
    C
    RRI
    2860.0
    [m]
    C
    RRI
    2863.0
    [m]
    C
    RRI
    2865.0
    [m]
    C
    RRI
    2869.0
    [m]
    C
    RRI
    2872.0
    [m]
    C
    RRI
    2874.0
    [m]
    C
    RRI
    2877.0
    [m]
    C
    RRI
    2878.0
    [m]
    C
    RRI
    2890.0
    [m]
    C
    RRI
    2891.0
    [m]
    C
    RRI
    2894.0
    [m]
    C
    RRI
    2897.0
    [m]
    C
    RRI
    2899.0
    [m]
    C
    RRI
    2902.0
    [m]
    C
    RRI
    2904.0
    [m]
    C
    RRI
    2907.0
    [m]
    C
    RRI
    2909.0
    [m]
    C
    RRI
    2913.0
    [m]
    C
    RRI
    2915.0
    [m]
    C
    RRI
    2918.0
    [m]
    C
    RRI
    2921.0
    [m]
    C
    RRI
    2924.0
    [m]
    C
    RRI
    2927.0
    [m]
    C
    RRI
    2934.0
    [m]
    C
    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
    DST
    TEST2
    2880.00
    2895.00
    07.08.1983 - 00:00
    YES
    DST
    TEST3
    2835.00
    2845.00
    22.06.1983 - 00:00
    YES
    DST
    TEST4
    2754.00
    2790.00
    CONDENSATE
    28.06.1983 - 06:20
    YES

  • Lithostratigraphy

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    1.66
    pdf
    5.03
    pdf
    1.27

  • Documents – reported by the production licence (period for duty of secrecy expired)

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    2934
    2944
    15.8
    2.0
    2881
    2891
    19.0
    3.0
    2835
    2845
    19.0
    4.0
    2754
    2790
    19.0
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    2.0
    3.0
    4.0
    Drill stem tests (DST)
    Test number
    Oil
    [Sm3/day]
    Gas
    [Sm3/day]
    Oil density
    [g/cm3]
    Gas grav. rel.air
    GOR
    [m3/m3]
    1.0
    2.0
    782
    192000
    0.820
    0.740
    245
    3.0
    734
    530000
    0.800
    0.720
    722
    4.0
    501
    635000
    0.760
    0.710
    1303

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CDL CNL GR CAL
    221
    3243
    CORGUN
    1901
    2601
    DIFL BHC GR SP
    135
    3453
    DLL MLL GR CAL
    2578
    3014
    FMT
    2688
    2980
    FMT
    2697
    2697
    FMT
    2889
    2889
    HR DIP
    305
    2582
    SP
    2650
    3012

  • 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
    221.0
    36
    222.0
    0.00
    LOT
    SURF.COND.
    20
    652.0
    26
    668.0
    1.55
    LOT
    INTERM.
    13 3/8
    1902.0
    17 1/2
    1915.0
    1.60
    LOT
    INTERM.
    9 5/8
    2580.0
    12 1/4
    2687.0
    1.80
    LOT
    LINER
    7
    3015.0
    8 1/2
    3015.0
    2.53
    LOT
    OPEN HOLE
    3400.0
    6
    3466.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    255
    1.06
    41.0
    waterbased
    668
    1.19
    32.0
    waterbased
    1669
    1.15
    40.0
    waterbased
    2206
    1.26
    50.0
    waterbased
    2687
    1.57
    62.0
    waterbased
    2912
    1.60
    61.0
    waterbased
    3205
    1.45
    58.0
    waterbased
    3464
    1.50
    60.0
    waterbased

  • 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