Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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22.12.2024 - 01:25
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6407/7-3

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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.
    6407/7-3
    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.
    NORWEGIAN SEA
    Field
    Name of the field the wellbore is related to.
    Discovery
    Name of the discovery the wellbore is related to.
    Well name
    Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    6407/7-3
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    NH 8604 ROW 763 COL. 745
    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.
    573-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.
    77
    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,
    03.03.1988
    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.
    18.05.1988
    Plugged and abondon date
    Date when the P&A-operations of the wellbore was finished, as reported by the operator to the Norwegian Offshore Directorate throught DDRS (Daily Drilling Reporting System). Only applied once pr. wellhead/surface location.
    17.09.2014
    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.
    18.05.1990
    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.
    09.03.2009
    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
    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.
    ILE FM
    2nd level with HC, age
    Age of lithostratigraphic unit, 2nd level, where hydrocarbons were encountered. Examples of legal values: CRETACEOUS, EARLY CRETACEOUS, LATE JURASSIC, EOCENE.
    EARLY JURASSIC
    2nd level with HC, formation
    Name of lithostartigraphic unit, 2nd 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.
    BÅT 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).
    3222.0
    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).
    3220.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    6.9
    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.
    LATE TRIASSIC
    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.
    GREY BEDS (INFORMAL)
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    64° 16' 44.34'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    7° 9' 0.13'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7129582.24
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    410422.66
    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.
    1229

  • Wellbore history
    General
    Well 6407/7-3 was drilled on the northern part of the A structure of the Njord Field. The main objectives of the well were to test the hydrocarbon potential of the Ile Formation, to test the hydrocarbon potential of the Tilje Formation above the oil down to level in the Tilje Formation in well 6407/7-1, and to obtain formation pressure data to indicate the relationship between the A-north and the A-east/A-central compartments.
    Operations and results
    Well 6407/7-3 was spudded with the semi-submersible installation Polar Pioneer on 3 March 1988 and drilled to TD at 3222 m in the Triassic Grey Beds. At 891 m, after setting of 30" casing, gas started to stream out of the casing. It was assumed that the gas came from the bottom of the hole, since there were no previous peaks on the MWD log. Three cement plugs were set in the interval 780 - 891 m, but the gas continued to stream. A plug was then set in the interval 510 - 570 m, and the gas stream decreased. The hole was drilled up again to 525 m, where 20" casing was set, originally not a part of the program. Two zones had shallow gas, 553 - 570 m and 652 - 685 m, which was in agreement with what was assumed in the site survey. Further drilling proceeded without any significant problems. The well was drilled with spud mud down to 536 m, with gel and seawater from 536 m to 1098 m, with Newdrill/KCl/PAC from 1098 m to 3048 m, and with Newdrill/PAC.
    Top Jurassic was encountered at 2795 with a 12 m thick Spekk Formation overlying the Middle Jurassic Not Formation. Top of the reservoir sections was encountered at 2851 m. Light oil was encountered in two differently pressured reservoir zones. The upper reservoir was the Ile Formation from 2851 to 2867 m with a net pay of 10.8 m. The lower reservoir was the Tilje Formation and into the Åre Formation. The oil bearing interval was from 2936.5 m and down to siltstones at 3068 m with a total net pay of 50.4 m. The Åre Formation (below 3014 m) was composed of siltstones, sandstones of low porosity and stringers of claystones. It constituted a minor part of the net pay.
    Shows were recorded in sandstones in the Nise, Kvitnos, and Lange Formations in the intervals 2062 - 2325 m and 2487 - 2872 m. Weak shows were recorded also below the oil bearing reservoirs down to 3205 m.
    Fourteen cores were cut in the well. Two were cut in the interval 2852 - 2893 m and the remaining from 2937 to 3103 m. While cutting the fourth core, there was an invasion of formation fluid into the hole due to a sudden increase in pore pressure. Heavy mud was circulated into the hole, and the well was brought under control. RFT pressures were recorded and a segregated sample was taken at 2855 m. It recovered ten litres of water, a small amount of gas, and no oil.
    The well was permanently abandoned on 18 May 1988 as an oil appraisal.
    Testing
    Three DST tests were performed in the well. DST 1 tested the interval 3046.8 - 3067.8 m and produced 16 Sm3 oil /day through a 25.4 mm choke. The oil density was 0.831 g/cm3. The down hole temperature in the test, measured at 3003.3 m, was 116 deg C.
    Two tests were planned from the interval 2990 - 3014 m. DST 2A produced 527 sm3 oil and 119389 Sm3 gas /day through a 50.8 mm choke. The GOR was 227 Sm3/Sm3, the oil density was 0.809 g/cm3, the gas gravity was 0.737 (air = 1) with 1% CO2 and less than 1 ppm H2S. The down hole temperature in the test, measured at 2889.1 m, was 113.7 deg C. DST 2B was not performed because the bottom hole pressure tool was lost during test 2A and the hole had to be killed.
    DST 3 tested the interval 2852.1 - 2867.9 m and produced 950 Sm3 oil and 396150 Sm3 gas /day through a 25.4 mm choke. The GOR was 417 Sm3/Sm3, the oil density was 0.808 g/cm3, the gas gravity was 0.745 (air = 1) with 2% CO2 and less than 1 ppm H2S. The down hole temperature in the test, measured at 2795.5 m, was 111.9 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]
    560.00
    3222.00

  • 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
    2852.0
    2871.7
    [m ]
    2
    2873.0
    2892.5
    [m ]
    3
    2937.0
    2946.2
    [m ]
    4
    2946.3
    2952.9
    [m ]
    5
    2953.0
    2967.6
    [m ]
    6
    2967.0
    2984.4
    [m ]
    7
    2984.4
    3012.3
    [m ]
    8
    3012.3
    3025.5
    [m ]
    9
    3025.5
    3030.6
    [m ]
    10
    3030.6
    3043.4
    [m ]
    11
    3043.5
    3069.0
    [m ]
    12
    3069.0
    3070.4
    [m ]
    13
    3071.0
    3085.0
    [m ]
    14
    3086.0
    3100.5
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    201.4
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1221.5
    [m]
    SWC
    HYDRO
    1292.0
    [m]
    SWC
    HYDRO
    1410.3
    [m]
    SWC
    HYDRO
    1558.3
    [m]
    SWC
    HYDRO
    1681.5
    [m]
    SWC
    HYDRO
    1729.0
    [m]
    SWC
    HYDRO
    1769.5
    [m]
    SWC
    HYDRO
    1814.8
    [m]
    SWC
    HYDRO
    1868.0
    [m]
    SWC
    HYDRO
    1900.0
    [m]
    SWC
    HYDRO
    1947.5
    [m]
    SWC
    HYDRO
    1999.6
    [m]
    SWC
    HYDRO
    2016.8
    [m]
    SWC
    HYDRO
    2078.8
    [m]
    SWC
    HYDRO
    2134.3
    [m]
    SWC
    HYDRO
    2184.5
    [m]
    SWC
    HYDRO
    2225.0
    [m]
    SWC
    HYDRO
    2267.2
    [m]
    SWC
    HYDRO
    2309.2
    [m]
    SWC
    HYDRO
    2350.5
    [m]
    SWC
    HYDRO
    2390.5
    [m]
    SWC
    HYDRO
    2449.0
    [m]
    SWC
    HYDRO
    2628.5
    [m]
    SWC
    HYDRO
    2673.0
    [m]
    SWC
    HYDRO
    2702.2
    [m]
    SWC
    HYDRO
    2730.0
    [m]
    SWC
    HYDRO
    2755.0
    [m]
    SWC
    HYDRO
    2765.0
    [m]
    SWC
    HYDRO
    2782.0
    [m]
    SWC
    HYDRO
    2790.0
    [m]
    SWC
    HYDRO
    2796.0
    [m]
    SWC
    HYDRO
    2797.0
    [m]
    SWC
    HYDRO
    2800.0
    [m]
    SWC
    HYDRO
    2805.0
    [m]
    SWC
    HYDRO
    2815.0
    [m]
    SWC
    HYDRO
    2823.0
    [m]
    SWC
    HYDRO
    2833.0
    [m]
    SWC
    HYDRO
    2837.5
    [m]
    SWC
    HYDRO
    2840.0
    [m]
    SWC
    HYDRO
    2845.0
    [m]
    SWC
    HYDRO
    2850.0
    [m]
    SWC
    HYDRO
    2852.5
    [m]
    C
    HYDRO
    2856.0
    [m]
    C
    HYDRO
    2856.8
    [m]
    C
    HYDRO
    2861.5
    [m]
    C
    HYDRO
    2868.0
    [m]
    C
    HYDRO
    2873.3
    [m]
    C
    HYDRO
    2876.0
    [m]
    C
    HYDRO
    2881.2
    [m]
    C
    HYDRO
    2887.0
    [m]
    C
    HYDRO
    2887.0
    [m]
    C
    HYDRO
    2890.0
    [m]
    C
    HYDRO
    2892.5
    [m]
    C
    HYDRO
    2915.0
    [m]
    SWC
    HYDRO
    2925.0
    [m]
    SWC
    HYDRO
    2933.0
    [m]
    SWC
    HYDRO
    2939.0
    [m]
    C
    HYDRO
    2944.0
    [m]
    C
    HYDRO
    2949.0
    [m]
    C
    HYDRO
    2953.0
    [m]
    C
    HYDRO
    2959.0
    [m]
    C
    HYDRO
    2969.2
    [m]
    C
    HYDRO
    2976.0
    [m]
    C
    HYDRO
    2984.4
    [m]
    C
    HYDRO
    2985.4
    [m]
    C
    HYDRO
    2990.0
    [m]
    C
    HYDRO
    2995.6
    [m]
    C
    HYDRO
    3010.9
    [m]
    C
    HYDRO
    3013.0
    [m]
    C
    HYDRO
    3030.6
    [m]
    C
    HYDRO
    3032.9
    [m]
    C
    HYDRO
    3035.0
    [m]
    C
    HYDRO
    3039.8
    [m]
    C
    HYDRO
    3047.4
    [m]
    C
    HYDRO
    3052.3
    [m]
    C
    HYDRO
    3064.4
    [m]
    C
    HYDRO
    3072.8
    [m]
    C
    HYDRO
    3084.7
    [m]
    C
    HYDRO
    3094.7
    [m]
    C
    HYDRO
    3108.0
    [m]
    SWC
    HYDRO
    3135.0
    [m]
    SWC
    HYDRO
    3155.0
    [m]
    SWC
    HYDRO
    3168.5
    [m]
    SWC
    HYDRO
    3180.0
    [m]
    SWC
    HYDRO
    3195.5
    [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
    DST2A
    2990.00
    3014.00
    08.05.1988 - 00:00
    YES
    DST
    DST3
    2852.00
    2867.00
    11.05.1988 - 00:00
    YES

  • Lithostratigraphy

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.31
    pdf
    2.46

  • 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
    10.13
    pdf
    4.68

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    3047
    3068
    25.4
    2.0
    2990
    3014
    50.8
    3.0
    2852
    2868
    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
    2.0
    3.0
    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
    16
    0.831
    2.0
    527
    119000
    0.809
    0.737
    227
    3.0
    950
    396000
    0.808
    0.745
    417

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    AMS
    1020
    2748
    AMS
    2736
    3222
    CBL VDL GR
    450
    1095
    CBL VDL GR
    2075
    2730
    CST GR
    1221
    2730
    CST GR
    2755
    3195
    CST GR
    2755
    3180
    DIL BHC GR SP
    400
    1057
    DIL BHC GR SP
    1020
    2748
    DIL SDT GR SP
    2736
    3225
    DLL MSFL SGR
    2736
    3222
    EVA SONIC
    2997
    3210
    EVA SONIC
    3080
    3120
    FMS AMS GR
    2740
    3226
    LDL CNL CAL GR
    1020
    2748
    LDL CNL NGS CAL
    2736
    3222
    MWD - GR RES DIR
    363
    1116
    MWD - GR RES DIR
    2753
    3221
    NGS
    2736
    3222
    RFT GR
    2855
    2880
    RFT GR
    2855
    3144
    RFT GR
    2860
    3004
    SHDT GR
    1099
    2749
    VSP
    700
    2700
    VSP
    900
    3150

  • 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
    442.0
    0.00
    LOT
    SURF.COND.
    20
    520.0
    26
    536.0
    1.37
    LOT
    INTERM.
    13 3/8
    1098.0
    17 1/2
    1116.0
    1.78
    LOT
    INTERM.
    9 5/8
    2731.0
    12 1/4
    2750.0
    1.75
    LOT
    LINER
    7
    3218.0
    8 1/2
    3222.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    394
    1.03
    WATER BASED
    03.03.1988
    440
    1.03
    WATER BASED
    04.03.1988
    442
    1.03
    WATER BASED
    07.03.1988
    480
    1.61
    18.0
    5.0
    WATER BASED
    19.05.1988
    480
    0.00
    WATER BASED
    20.05.1988
    510
    1.08
    WATER BASED
    08.03.1988
    525
    1.05
    WATER BASED
    09.03.1988
    525
    1.05
    WATER BASED
    10.03.1988
    536
    1.07
    5.0
    7.0
    WATER BASED
    11.03.1988
    811
    1.14
    5.0
    7.0
    WATER BASED
    14.03.1988
    891
    1.03
    WATER BASED
    07.03.1988
    1116
    1.14
    6.0
    11.0
    WATER BASED
    14.03.1988
    1116
    1.15
    7.0
    12.0
    WATER BASED
    14.03.1988
    1116
    1.14
    5.0
    9.0
    WATER BASED
    15.03.1988
    1176
    1.53
    12.0
    7.0
    WATER BASED
    16.03.1988
    1649
    1.60
    15.0
    9.0
    WATER BASED
    17.03.1988
    2151
    1.60
    18.0
    9.0
    WATER BASED
    18.03.1988
    2233
    1.60
    17.0
    8.0
    WATER BASED
    21.03.1988
    2407
    1.60
    18.0
    14.0
    WATER BASED
    21.03.1988
    2465
    1.60
    15.0
    13.0
    WATER BASED
    21.03.1988
    2560
    1.60
    16.0
    13.0
    WATER BASED
    22.03.1988
    2658
    1.60
    18.0
    8.0
    WATER BASED
    24.03.1988
    2711
    1.60
    18.0
    9.0
    WATER BASED
    24.03.1988
    2745
    1.61
    18.0
    5.0
    WATER BASED
    19.05.1988
    2750
    1.60
    14.0
    6.0
    WATER BASED
    25.03.1988
    2750
    1.60
    17.0
    9.0
    WATER BASED
    28.03.1988
    2750
    1.60
    18.0
    10.0
    WATER BASED
    28.03.1988
    2750
    1.60
    10.0
    5.0
    WATER BASED
    28.03.1988
    2753
    1.59
    12.0
    13.0
    WATER BASED
    29.03.1988
    2841
    1.46
    18.0
    5.0
    WATER BASED
    05.04.1988
    2873
    1.46
    19.0
    5.0
    WATER BASED
    06.04.1988
    2898
    1.46
    16.0
    5.0
    WATER BASED
    06.04.1988
    2922
    1.60
    15.0
    5.0
    WATER BASED
    16.05.1988
    2922
    1.60
    15.0
    6.0
    WATER BASED
    16.05.1988
    2922
    1.61
    18.0
    5.0
    WATER BASED
    16.05.1988
    2937
    1.46
    20.0
    6.0
    WATER BASED
    06.04.1988
    2947
    1.46
    20.0
    6.0
    WATER BASED
    06.04.1988
    2965
    1.52
    22.0
    6.0
    WATER BASED
    06.04.1988
    2984
    1.52
    22.0
    6.0
    WATER BASED
    06.04.1988
    3018
    1.52
    22.0
    6.0
    WATER BASED
    06.04.1988
    3030
    1.52
    22.0
    6.0
    WATER BASED
    07.04.1988
    3041
    1.60
    22.0
    4.0
    WATER BASED
    02.05.1988
    3041
    1.60
    21.0
    4.0
    WATER BASED
    03.05.1988
    3041
    1.60
    18.0
    6.0
    WATER BASED
    05.05.1988
    3041
    1.60
    16.0
    5.0
    WATER BASED
    06.05.1988
    3041
    1.60
    16.0
    6.0
    WATER BASED
    09.05.1988
    3041
    1.60
    19.0
    6.0
    WATER BASED
    13.05.1988
    3041
    1.60
    21.0
    6.0
    WATER BASED
    10.05.1988
    3041
    1.60
    18.0
    6.0
    WATER BASED
    04.05.1988
    3041
    1.60
    18.0
    6.0
    WATER BASED
    09.05.1988
    3048
    1.52
    19.0
    4.0
    WATER BASED
    08.04.1988
    3071
    1.52
    21.0
    5.0
    WATER BASED
    11.04.1988
    3102
    1.52
    22.0
    5.0
    WATER BASED
    11.04.1988
    3162
    1.52
    23.0
    6.0
    WATER BASED
    11.04.1988
    3222
    1.52
    22.0
    5.0
    WATER BASED
    12.04.1988
    3222
    1.52
    19.0
    5.0
    WATER BASED
    14.04.1988
    3222
    1.52
    24.0
    5.0
    WATER BASED
    15.04.1988
    3222
    1.52
    27.0
    4.0
    WATER BASED
    19.04.1988
    3222
    1.52
    23.0
    6.0
    WATER BASED
    19.04.1988
    3222
    1.52
    29.0
    5.0
    WATER BASED
    19.04.1988
    3222
    1.56
    24.0
    5.0
    WATER BASED
    20.04.1988
    3222
    1.56
    21.0
    6.0
    WATER BASED
    22.04.1988
    3222
    1.60
    23.0
    7.0
    WATER BASED
    22.04.1988
    3222
    1.60
    24.0
    5.0
    WATER BASED
    27.04.1988
    3222
    1.60
    23.0
    5.0
    WATER BASED
    27.04.1988
    3222
    1.60
    25.0
    5.0
    WATER BASED
    27.04.1988
    3222
    1.60
    23.0
    4.0
    WATER BASED
    27.04.1988
    3222
    1.60
    23.0
    4.0
    WATER BASED
    29.04.1988
    3222
    1.60
    22.0
    5.0
    WATER BASED
    02.05.1988
    3222
    1.52
    19.0
    5.0
    WATER BASED
    13.04.1988
    3222
    1.52
    25.0
    4.0
    WATER BASED
    19.04.1988
    3222
    1.60
    23.0
    4.0
    WATER BASED
    02.05.1988

  • 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
    0.23