Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
25.11.2024 - 01:30
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34/8-11

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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.
    34/8-11
    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.
    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.
    34/8-11
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    nh 9001 - 30: inline 817& crossline 625
    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.
    780-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.
    61
    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,
    10.12.1993
    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.
    08.02.1994
    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.
    08.02.1996
    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.
    21.12.2012
    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
    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.
    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.
    23.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    332.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3140.0
    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).
    3137.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    7.1
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    119
    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.
    COOK FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    61° 21' 46.94'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 27' 37.54'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6803506.68
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    471149.22
    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.
    2180

  • Wellbore history
    General
    Well 34/8-11 was drilled to appraise the 34/8-1 Visund discovery on Tampen Spur in the Northern North Sea. The main objective was to verify the extension of the Brent reservoir and fluid type encountered in Well 34/8-8.
    Operations and results
    Appraisal well 34/8-11 was spudded with the semi-submersible installation Polar Pioneer on 10 December 1993 and drilled to TD at 3140 m in the Early Jurassic Cook Formation. No significant problem was encountered in the operations. The well was drilled with seawater and hi-vis pills down to 1295 m, and with the ANCO 2000 glycol mud system from 1295 m to TD.
    A 1.5 m thick section of the Draupne Formation was encountered at 2852.5 m on top of a 15 m thick Heather Formation at 2854 m. The Brent Group was encountered at 2869 m. The Brent Group contained oil-bearing sandstones in the Tarbert, Ness, Etive and Rannoch Formations. A gross Brent reservoir thickness of 142 m was defined, giving a net pay of 69.4 m. From MDT pressures and logs an OWC was indicated between 2960 and 2965 m in the Rannoch Formation, however, moveable oil appears to be present all through the Rannoch. Reservoir geochemistry of core extracts indicate a shift from unaltered oil to slightly biodegraded residual oil somewhere between 2969 m and 2986 m. Good oil shows were recorded on the cores down to 3005 m otherwise no other oil shows were described in the well.
    Eight cores were cut in succession from 2859 to 3008 m, covering the lower half of the heather Formation and all of the Brent Formation. The core depth shifts relative to the logs were in the range -1.5 m to - 2.0 m; except for core no 4, which had a core-log shift of + 0.125 m.  MDT fluid samples were taken at 2876.5 m. 2923 m, 2933 m, 2948 m, and at 2964 m.
    The well was permanently abandoned on 8 February 1994 as an oil appraisal well.
    Testing
    Two drill stem tests were conducted in the Brent Group.
    DST 1A tested the interval 2942.2 - 2956.2 m. It produced 1142 Sm3 oil and 285300 Sm3 gas /day through a 40/64" choke. The GOR was 250 Sm3/Sm3, the oil density was 0.841 g/cm3, and the gas gravity was 0.755 (air = 1) with only a trace CO2. The bottom hole temperature measured at 2848.86 m was 111.6 deg C.
    DST 2B tested the intervals 2913.2 - 2939.0 m plus 2942.2 - 2956.2 m. It produced 1135 Sm3 oil and 291800 Sm3 gas /day through a 40/64" choke. The GOR was 257 Sm3/Sm3, the oil density was 0.839 g/cm3, and the gas gravity was 0.735 (air = 1) with 1.2 % CO2. The bottom hole temperature measured at 2848.86 m was 112.3 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]
    1295.00
    3140.00

  • 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
    2859.0
    2871.0
    [m ]
    2
    2871.0
    2889.0
    [m ]
    3
    2889.0
    2896.2
    [m ]
    4
    2915.0
    2929.2
    [m ]
    5
    2932.0
    2960.0
    [m ]
    6
    2960.0
    2986.4
    [m ]
    7
    2986.4
    3000.2
    [m ]
    8
    3002.0
    3005.4
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    123.0
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 2859-2864m
    Core photo at depth: 2864-2869m
    Core photo at depth: 2869-2871m
    Core photo at depth: 2971-2876m
    Core photo at depth: 2876-2881m
    2859-2864m
    2864-2869m
    2869-2871m
    2971-2876m
    2876-2881m
    Core photo at depth: 2881-2886m
    Core photo at depth: 2886-2889m
    Core photo at depth: 2889-2894m
    Core photo at depth: 2894-2896m
    Core photo at depth: 2915-2920m
    2881-2886m
    2886-2889m
    2889-2894m
    2894-2896m
    2915-2920m
    Core photo at depth: 2920-2925m
    Core photo at depth: 2925-2929m
    Core photo at depth: 2932-2937m
    Core photo at depth: 2937-2942m
    Core photo at depth: 2942-2947m
    2920-2925m
    2925-2929m
    2932-2937m
    2937-2942m
    2942-2947m
    Core photo at depth: 2947-2952m
    Core photo at depth: 2952-2957m
    Core photo at depth: 2957-2960m
    Core photo at depth: 2960-2965m
    Core photo at depth: 2965-2970m
    2947-2952m
    2952-2957m
    2957-2960m
    2960-2965m
    2965-2970m
    Core photo at depth: 2970-2975m
    Core photo at depth: 2975-2980m
    Core photo at depth: 2980-2985m
    Core photo at depth: 2985-2986m
    Core photo at depth: 2986-2991m
    2970-2975m
    2975-2980m
    2980-2985m
    2985-2986m
    2986-2991m
    Core photo at depth: 2991-2996m
    Core photo at depth: 2996-3000m
    Core photo at depth: 3002-3005m
    Core photo at depth:  
    Core photo at depth:  
    2991-2996m
    2996-3000m
    3002-3005m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1310.0
    [m]
    DC
    GEOST
    1340.0
    [m]
    DC
    GEOST
    1355.0
    [m]
    DC
    GEOST
    1385.0
    [m]
    DC
    GEOST
    1400.0
    [m]
    DC
    GEOST
    1430.0
    [m]
    DC
    GEOST
    1445.0
    [m]
    DC
    GEOST
    1475.0
    [m]
    DC
    GEOST
    1490.0
    [m]
    DC
    GEOST
    1520.0
    [m]
    DC
    GEOST
    1535.0
    [m]
    DC
    GEOST
    1565.0
    [m]
    DC
    GEOST
    1580.0
    [m]
    DC
    GEOST
    1610.0
    [m]
    DC
    GEOST
    1625.0
    [m]
    DC
    GEOST
    1655.0
    [m]
    DC
    GEOST
    1670.0
    [m]
    DC
    GEOST
    1700.0
    [m]
    DC
    GEOST
    1715.0
    [m]
    DC
    GEOST
    1745.0
    [m]
    DC
    GEOST
    1760.0
    [m]
    DC
    GEOST
    1790.0
    [m]
    DC
    GEOST
    1805.0
    [m]
    DC
    GEOST
    1820.0
    [m]
    DC
    GEOST
    1835.0
    [m]
    DC
    GEOST
    1850.0
    [m]
    DC
    GEOST
    1880.0
    [m]
    DC
    GEOST
    1895.0
    [m]
    DC
    GEOST
    1925.0
    [m]
    DC
    GEOST
    1935.0
    [m]
    DC
    GEOST
    1945.0
    [m]
    DC
    GEOST
    1965.0
    [m]
    DC
    GEOST
    1970.0
    [m]
    DC
    GEOST
    1980.0
    [m]
    DC
    GEOST
    2010.0
    [m]
    DC
    GEOST
    2025.0
    [m]
    DC
    GEOST
    2040.0
    [m]
    DC
    GEOST
    2070.0
    [m]
    DC
    GEOST
    2085.0
    [m]
    DC
    GEOST
    2100.0
    [m]
    DC
    GEOST
    2130.0
    [m]
    DC
    GEOST
    2145.0
    [m]
    DC
    GEOST
    2175.0
    [m]
    DC
    GEOST
    2190.0
    [m]
    DC
    GEOST
    2205.0
    [m]
    DC
    GEOST
    2220.0
    [m]
    DC
    GEOST
    2235.0
    [m]
    DC
    GEOST
    2265.0
    [m]
    DC
    GEOST
    2280.0
    [m]
    DC
    GEOST
    2310.0
    [m]
    DC
    GEOST
    2325.0
    [m]
    DC
    GEOST
    2355.0
    [m]
    DC
    GEOST
    2370.0
    [m]
    DC
    GEOST
    2385.0
    [m]
    DC
    GEOST
    2400.0
    [m]
    DC
    GEOST
    2415.0
    [m]
    DC
    GEOST
    2445.0
    [m]
    DC
    GEOST
    2460.0
    [m]
    DC
    GEOST
    2490.0
    [m]
    DC
    GEOST
    2505.0
    [m]
    DC
    GEOST
    2535.0
    [m]
    DC
    GEOST
    2550.0
    [m]
    DC
    GEOST
    2580.0
    [m]
    DC
    GEOST
    2595.0
    [m]
    DC
    GEOST
    2620.0
    [m]
    DC
    GEOST
    2640.0
    [m]
    DC
    GEOST
    2660.0
    [m]
    DC
    GEOST
    2680.0
    [m]
    DC
    GEOST
    2700.0
    [m]
    DC
    GEOST
    2720.0
    [m]
    DC
    GEOST
    2740.0
    [m]
    DC
    GEOST
    2760.0
    [m]
    DC
    GEOST
    2780.0
    [m]
    DC
    GEOST
    2800.0
    [m]
    DC
    GEOST
    2820.0
    [m]
    DC
    GEOST
    2840.0
    [m]
    DC
    GEOST
    2850.0
    [m]
    DC
    GEOST
    2852.0
    [m]
    DC
    GEOST
    2855.0
    [m]
    DC
    GEOST
    2857.0
    [m]
    DC
    GEOST
    2859.0
    [m]
    C
    GEOST
    2862.8
    [m]
    C
    GEOST
    2863.8
    [m]
    C
    GEOST
    2864.4
    [m]
    C
    GEOST
    2864.9
    [m]
    C
    GEOST
    2866.0
    [m]
    C
    GEOST
    2870.1
    [m]
    C
    GEOST
    2881.0
    [m]
    C
    GEOST
    2889.0
    [m]
    C
    GEOST
    2895.6
    [m]
    C
    GEOST
    2910.0
    [m]
    DC
    GEOST
    2926.0
    [m]
    C
    GEOST
    2935.9
    [m]
    C
    GEOST
    2944.0
    [m]
    C
    GEOST
    2956.5
    [m]
    C
    GEOST
    2962.4
    [m]
    C
    GEOST
    2974.0
    [m]
    C
    GEOST
    2978.5
    [m]
    C
    GEOST
    2985.0
    [m]
    C
    GEOST
    2990.0
    [m]
    C
    GEOST
    2995.5
    [m]
    C
    GEOST
    2999.0
    [m]
    C
    GEOST
    3005.4
    [m]
    C
    GEOST

  • 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
    DST1
    2950.10
    2936.10
    13.01.1994 - 08:35
    YES

  • Lithostratigraphy

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.60

  • 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
    14.20

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    2942
    2956
    15.8
    2.0
    2913
    2956
    15.8
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    111
    2.0
    112
    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
    1142
    285300
    0.841
    0.755
    250
    2.0
    1135
    291800
    0.839
    0.735
    257

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL VDL
    2318
    2977
    CBL VDL
    2800
    2985
    DLL LSS GR AMS SP
    355
    2689
    DLL MSFL LSS GR SP AMS
    2698
    3141
    EPT
    2698
    3111
    FMI GR
    2698
    3037
    LDL CNL GR
    355
    1291
    LDL CNL GR ACTS
    2698
    3028
    MDT SGR AMS
    10
    3020
    MDT SGR AMS
    2876
    2876
    MDT SGR AMS
    2948
    2964
    NGT RATIOS
    2698
    3003
    VSP
    1500
    3080

  • 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
    440.0
    36
    440.0
    0.00
    LOT
    SURF.COND.
    13 3/8
    1280.0
    17 1/2
    1295.0
    0.00
    LOT
    INTERM.
    9 5/8
    2696.0
    12 1/4
    2711.0
    0.00
    LOT
    LINER
    7
    3138.0
    8 1/2
    3140.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    440
    1.20
    WATER BASED
    15.12.1993
    794
    1.06
    WATER BASED
    15.12.1993
    1204
    1.55
    22.0
    5.5
    WATER BASED
    04.02.1994
    1204
    1.55
    21.0
    7.0
    WATER BASED
    07.02.1994
    1295
    1.20
    WATER BASED
    15.12.1993
    1295
    1.20
    WATER BASED
    15.12.1993
    1295
    1.20
    WATER BASED
    15.12.1993
    1295
    1.20
    WATER BASED
    20.12.1993
    1295
    1.20
    WATER BASED
    20.12.1993
    1668
    1.50
    34.0
    11.0
    WATER BASED
    22.12.1993
    2025
    1.50
    30.0
    9.5
    WATER BASED
    22.12.1993
    2400
    1.50
    33.0
    10.0
    WATER BASED
    22.12.1993
    2711
    1.51
    25.0
    7.5
    WATER BASED
    22.12.1993
    2711
    1.51
    24.0
    7.0
    WATER BASED
    23.12.1993
    2711
    1.51
    24.0
    8.0
    WATER BASED
    22.12.1993
    2733
    1.68
    32.0
    8.5
    WATER BASED
    28.12.1993
    2786
    1.68
    34.0
    8.5
    WATER BASED
    28.12.1993
    2856
    1.68
    35.0
    8.0
    WATER BASED
    28.12.1993
    2884
    1.68
    34.0
    7.0
    WATER BASED
    28.12.1993
    2889
    1.66
    23.0
    6.5
    WATER BASED
    03.02.1994
    2914
    1.68
    31.0
    6.0
    WATER BASED
    28.12.1993
    2932
    1.68
    36.0
    7.5
    WATER BASED
    29.12.1993
    2986
    1.68
    36.0
    7.0
    WATER BASED
    30.12.1993
    2994
    1.68
    33.0
    7.0
    WATER BASED
    31.12.1993
    3008
    1.68
    38.0
    7.5
    WATER BASED
    03.01.1994
    3090
    1.66
    33.0
    10.0
    WATER BASED
    20.01.1994
    3090
    1.66
    34.0
    10.0
    WATER BASED
    25.01.1994
    3090
    1.66
    34.0
    10.0
    WATER BASED
    25.01.1994
    3090
    1.66
    34.0
    10.0
    WATER BASED
    25.01.1994
    3140
    1.66
    25.0
    7.0
    WATER BASED
    27.01.1994
    3140
    1.68
    37.0
    8.0
    WATER BASED
    06.01.1994
    3140
    1.66
    38.0
    10.0
    WATER BASED
    11.01.1994
    3140
    1.66
    38.0
    10.0
    WATER BASED
    12.01.1994
    3140
    1.66
    33.0
    10.0
    WATER BASED
    18.01.1994
    3140
    1.66
    33.0
    10.0
    WATER BASED
    18.01.1994
    3140
    1.68
    39.0
    9.5
    WATER BASED
    03.01.1994
    3140
    1.68
    39.0
    9.5
    WATER BASED
    03.01.1994
    3140
    1.68
    39.0
    9.5
    WATER BASED
    04.01.1994
    3140
    1.68
    37.0
    8.0
    WATER BASED
    06.01.1994
    3140
    1.66
    38.0
    10.0
    WATER BASED
    07.01.1994
    3140
    1.66
    38.0
    10.0
    WATER BASED
    10.01.1994
    3140
    1.66
    38.0
    10.0
    WATER BASED
    10.01.1994
    3140
    1.66
    38.0
    10.0
    WATER BASED
    10.01.1994
    3140
    1.66
    36.0
    8.5
    WATER BASED
    13.01.1994
    3140
    1.66
    36.0
    8.5
    WATER BASED
    17.01.1994
    3140
    1.66
    35.0
    9.0
    WATER BASED
    18.01.1994
    3140
    1.66
    33.0
    10.0
    WATER BASED
    18.01.1994

  • 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
    0.21