Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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14.07.2024 - 01:28
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34/8-3

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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.
    34/8-3
    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.
    34/8-3
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    NH 8404 - 321 SP 275
    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.
    581-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.
    63
    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,
    14.07.1988
    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.
    14.09.1988
    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.
    14.09.1990
    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.
    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.
    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.
    382.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3328.0
    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).
    3320.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    9.6
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    122
    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° 24' 28.04'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 32' 45.06'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6808456.80
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    475751.35
    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.
    940
  • Wellbore history

    General
    Well 34/8-3 was drilled on the A-structure on the Visund Field. This is a NNE-SSW oriented elongated fault block with the Pre-Cretaceous strata dipping towards WNW. The A-Central fault divides the A-structure into the A-North and A-South compartments. The primary objectives of the well were to test the hydrocarbon potential of the Brent Group on the A-North compartment. Planned TD was 50 m into the Statfjord Formation.
    Operations and results
    Wildcat well 34/8-3 was spudded with the semi-submersible installation Polar Pioneer on 14 July 1988 and drilled to TD at 3328 m (3320 m TVD) in the Early Jurassic Statfjord Formation. There were no problems with shallow gas. 9 5/8" casing was set at 2597 m instead of 2800 m due to higher pressure than prognosed in formation of Cretaceous age. Below 2600 m the well started to build some angle, up to 9.6 deg at the most. This resulted in 8 meter discrepancy between measured depth and vertical depth towards TD. The well was drilled with seawater and hi-vis pills down to 1302 m and with KCl/polymer mud from 1302 m to TD.
    Oil shows were recorded in thin sandstone stringers in the Kyrre Formation between 2364 m and 2555 m. The Brent Group was encountered at 2837 m. It contained a 90 m gas column and a 13 m oil column. The gas/oil contact was at 2929 m. The oil/water contact could not be established, but DST 1 produced clean oil from the interval 2935 to 2947 m. Oil shows were recorded on sandstone on cores down to 2951 m.
    Seven cores were cut in the interval 2839.0 to 2957.5 m in the Brent Group. The core depths are 1 m shallow compared to logger's depth. One RFT wire line fluid sample was taken at 2936 m. The 2 3/4 gallon chamber contained 9 litres water and mud filtrate, 0.6 litres oil and 0.14 Sm3 gas.
    Since the oil/water contact was not found, it was decided to sidetrack. The well bore was plugged back to 845 m and permanently abandoned on 14 September 1988 as an oil and gas appraisal well.
    Testing
    Three drill stem tests were performed in the well.
    DST 1 tested the interval from 2935 to 2947 m in the oil zone in the Rannoch Formation. It produced 68 Sm3 oil and 18200 Sm3 gas /day through a 4.76 mm (12/64") choke. The GOR was 268 Sm3/Sm3, the oil density was 0.847 g/cm3, and the gas gravity was 0.635 (air = 1) with 1 % CO2 and 0 ppm H2S. The bottom hole temperature was 108.9 deg C, measured at 2895.8 m.
    DST 2 tested the interval from 2905 to 2921 m in the gas zone in the Rannoch Formation. It produced 613 Sm3 oil and 1540000 Sm3 gas /day through a 28.58 mm (72/64") choke. The GOR was 2520 Sm3/Sm3, the oil density was 0.0.775 g/cm3, and the gas gravity was 0.640 (air = 1) with 1.6 % CO2 and 1 ppm H2S. The bottom hole temperature was 110.8 deg C, measured at 2850.11 m.
    DST 3 tested the interval from 2868 to 2880 m in the gas zone in the Etive Formation. It produced 554 Sm3 oil and 1540000 Sm3 gas /day through a 25.4 mm (64/64") choke. The GOR was 2780 Sm3/Sm3, the oil density was 0.782 g/cm3, and the gas gravity was 0.648 (air = 1) with 1.5 % CO2 and 1 ppm H2S. The bottom hole temperature was 110.4 deg C, measured at 2825.56 m.
  • 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]
    1320.00
    3327.00
  • 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
    2839.0
    2849.0
    [m ]
    2
    2849.0
    2871.0
    [m ]
    3
    2871.0
    2895.0
    [m ]
    4
    2895.0
    2898.5
    [m ]
    5
    2899.0
    2927.0
    [m ]
    6
    2927.0
    2946.0
    [m ]
    7
    2946.0
    2957.1
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    117.6
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES
  • Core photos

    Core photos
    Core photo at depth: 2839-2843m
    Core photo at depth: 2846-2851m
    Core photo at depth: 2851-2856m
    Core photo at depth: 2856-2861m
    Core photo at depth: 2861-2866m
    2839-2843m
    2846-2851m
    2851-2856m
    2856-2861m
    2861-2866m
    Core photo at depth: 2866-2873m
    Core photo at depth: 2873-2878m
    Core photo at depth: 2878-2883m
    Core photo at depth: 2878-2883m
    Core photo at depth: 2883-2888m
    2866-2873m
    2873-2878m
    2878-2883m
    2878-2883m
    2883-2888m
    Core photo at depth: 2888-2893m
    Core photo at depth: 2893-2897m
    Core photo at depth: 2898-2903m
    Core photo at depth: 2903-2908m
    Core photo at depth: 2908-2913m
    2888-2893m
    2893-2897m
    2898-2903m
    2903-2908m
    2908-2913m
    Core photo at depth: 2913-2918m
    Core photo at depth: 2923-2927m
    Core photo at depth: 2918-2923m
    Core photo at depth: 2927-2932m
    Core photo at depth: 2932-2937m
    2913-2918m
    2923-2927m
    2918-2923m
    2927-2932m
    2932-2937m
    Core photo at depth: 2937-2942m
    Core photo at depth: 2942-2947m
    Core photo at depth: 2947-2953m
    Core photo at depth: 2953-2957m
    Core photo at depth:  
    2937-2942m
    2942-2947m
    2947-2953m
    2953-2957m
  • Palynological slides at the Norwegian Offshore Directorate

    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    2641.0
    [m]
    SWC
    HYDRO
    2690.0
    [m]
    SWC
    HYDRO
    2733.0
    [m]
    SWC
    HYDRO
    2770.0
    [m]
    SWC
    HYDRO
    2810.0
    [m]
    DC
    HYDRO
    2820.0
    [m]
    DC
    HYDRO
    2824.0
    [m]
    SWC
    HYDRO
    2827.5
    [m]
    SWC
    HYDRO
    2828.0
    [m]
    SWC
    HYDRO
    2835.0
    [m]
    SWC
    HYDRO
    2837.0
    [m]
    SWC
    HYDRO
    2839.0
    [m]
    C
    HYDRO
    2839.9
    [m]
    C
    HYDRO
    2840.0
    [m]
    DC
    HYDRO
    2842.0
    [m]
    C
    HYDRO
    2852.0
    [m]
    C
    HYDRO
    2852.5
    [m]
    C
    HYDRO
    2855.0
    [m]
    DC
    HYDRO
    2855.1
    [m]
    C
    HYDRO
    2860.9
    [m]
    C
    HYDRO
    2861.0
    [m]
    C
    HYDRO
    2866.0
    [m]
    C
    HYDRO
    2876.2
    [m]
    C
    HYDRO
    2880.3
    [m]
    C
    HYDRO
    2931.0
    [m]
    C
    HYDRO
    2931.0
    [m]
    C
    HYDRO
    2933.4
    [m]
    C
    HYDRO
    2934.0
    [m]
    C
    HYDRO
    2935.2
    [m]
    C
    HYDRO
    2942.1
    [m]
    C
    HYDRO
    2947.0
    [m]
    C
    HYDRO
    2952.4
    [m]
    C
    HYDRO
    2955.0
    [m]
    DC
    HYDRO
    2956.8
    [m]
    C
    HYDRO
    2957.2
    [m]
    C
    HYDRO
    2962.0
    [m]
    DC
    HYDRO
    2970.0
    [m]
    DC
    HYDRO
    2985.0
    [m]
    DC
    HYDRO
    2995.7
    [m]
    SWC
    HYDRO
    2997.5
    [m]
    SWC
    HYDRO
    3000.0
    [m]
    DC
    HYDRO
    3015.0
    [m]
    DC
    HYDRO
    3030.0
    [m]
    SWC
    HYDRO
    3034.0
    [m]
    SWC
    HYDRO
    3045.5
    [m]
    SWC
    HYDRO
    3075.0
    [m]
    SWC
    HYDRO
    3128.0
    [m]
    SWC
    HYDRO
    3155.0
    [m]
    SWC
    HYDRO
    3165.0
    [m]
    SWC
    HYDRO
    3180.0
    [m]
    SWC
    HYDRO
    3220.0
    [m]
    SWC
    HYDRO
    3273.0
    [m]
    SWC
    HYDRO
    3277.0
    [m]
    SWC
    HYDRO
  • 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
    0.00
    0.00
    YES
    DST
    TEST1
    2935.00
    2947.00
    18.08.1988 - 00:00
    YES
    DST
    DST2
    2905.00
    2921.00
    30.08.1988 - 00:00
    YES
    DST
    DST3
    2868.00
    2880.00
    CONDENSATE
    08.09.1988 - 00:00
    YES
  • Lithostratigraphy

  • Geochemical information

    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.58
  • 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
    5.06
    pdf
    15.67
  • Drill stem tests (DST)

    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    2935
    2947
    4.8
    2.0
    2905
    2921
    28.6
    3.0
    2868
    2880
    25.4
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    109
    2.0
    110
    3.0
    110
    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
    68
    18200
    0.847
    0.635
    268
    2.0
    613
    1540000
    0.775
    0.640
    2520
    3.0
    554
    1540000
    0.782
    0.648
    2776
  • Logs

    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    AMS
    2597
    3328
    CBL VDL
    1200
    3232
    CST GR
    2733
    3306
    DIL LSS GR SP
    1090
    3328
    DLL MSFL
    2597
    3328
    LDL CNL
    1090
    3328
    MWD
    402
    2838
    NGS
    2597
    3328
    RFT
    2842
    3302
    SHDT
    2597
    3312
    VSP
    800
    3230
  • 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
    491.0
    36
    970.0
    0.00
    LOT
    INTERM.
    13 3/8
    1302.0
    17 1/2
    1317.0
    1.63
    LOT
    INTERM.
    9 5/8
    2598.0
    12 1/4
    2622.0
    1.86
    LOT
    LINER
    7
    3312.0
    8 1/2
    3328.0
    0.00
    LOT
  • Drilling mud

    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    419
    1.03
    WATER BASED
    15.07.1988
    482
    1.03
    WATER BASED
    19.07.1988
    491
    1.03
    WATER BASED
    19.07.1988
    970
    1.03
    WATER BASED
    19.07.1988
    1317
    1.03
    WATER BASED
    19.07.1988
    1317
    1.03
    WATER BASED
    21.07.1988
    1317
    1.20
    15.0
    8.0
    WATER BASED
    27.07.1988
    1864
    1.36
    22.0
    13.0
    WATER BASED
    27.07.1988
    2312
    1.41
    26.0
    16.0
    WATER BASED
    27.07.1988
    2390
    1.52
    19.0
    6.0
    WATER BASED
    13.09.1988
    2390
    1.52
    20.0
    8.0
    WATER BASED
    14.09.1988
    2390
    1.52
    20.0
    8.0
    WATER BASED
    15.09.1988
    2469
    1.46
    24.0
    9.0
    WATER BASED
    27.07.1988
    2622
    1.52
    26.0
    8.0
    WATER BASED
    27.07.1988
    2622
    1.52
    25.0
    8.0
    WATER BASED
    27.07.1988
    2622
    1.52
    25.0
    8.0
    WATER BASED
    28.07.1988
    2627
    1.52
    20.0
    6.0
    WATER BASED
    01.08.1988
    2749
    1.52
    24.0
    8.0
    WATER BASED
    01.08.1988
    2839
    1.60
    25.0
    8.0
    WATER BASED
    01.08.1988
    2870
    1.60
    23.0
    6.0
    WATER BASED
    01.08.1988
    2897
    1.70
    24.0
    8.0
    WATER BASED
    09.09.1988
    2897
    1.70
    25.0
    8.0
    WATER BASED
    08.09.1988
    2933
    1.70
    24.0
    9.0
    WATER BASED
    02.09.1988
    2933
    1.70
    24.0
    9.0
    WATER BASED
    05.09.1988
    2933
    1.70
    25.0
    9.0
    WATER BASED
    06.09.1988
    2933
    1.70
    24.0
    8.0
    WATER BASED
    07.09.1988
    2957
    1.60
    24.0
    6.0
    WATER BASED
    04.08.1988
    2992
    1.60
    23.0
    7.0
    WATER BASED
    08.08.1988
    3066
    1.60
    21.0
    7.0
    WATER BASED
    08.08.1988
    3169
    1.60
    24.0
    7.0
    WATER BASED
    08.08.1988
    3216
    1.60
    24.0
    8.0
    WATER BASED
    08.08.1988
    3264
    1.60
    22.0
    10.0
    WATER BASED
    09.08.1988
    3316
    1.66
    25.0
    9.0
    WATER BASED
    23.08.1988
    3316
    1.66
    21.0
    10.0
    WATER BASED
    23.08.1988
    3316
    1.70
    25.0
    9.0
    WATER BASED
    30.08.1988
    3316
    1.70
    24.0
    9.0
    WATER BASED
    31.08.1988
    3316
    1.66
    25.0
    10.0
    WATER BASED
    19.08.1988
    3316
    1.66
    24.0
    10.0
    WATER BASED
    19.08.1988
    3316
    1.69
    24.0
    9.0
    WATER BASED
    25.08.1988
    3316
    1.69
    24.0
    9.0
    WATER BASED
    26.08.1988
    3316
    1.69
    24.0
    9.0
    WATER BASED
    29.08.1988
    3316
    1.70
    24.0
    9.0
    WATER BASED
    30.08.1988
    3328
    1.60
    23.0
    9.0
    WATER BASED
    15.08.1988
    3328
    1.60
    23.0
    9.0
    WATER BASED
    10.08.1988
    3328
    1.60
    23.0
    9.0
    WATER BASED
    11.08.1988
    3328
    1.60
    24.0
    9.0
    WATER BASED
    12.08.1988
    3328
    1.66
    29.0
    6.0
    WATER BASED
    15.08.1988
    3328
    1.66
    29.0
    7.0
    WATER BASED
    15.08.1988
    3328
    1.66
    29.0
    10.0
    WATER BASED
    16.08.1988
  • 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