Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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23.07.2024 - 01:26
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35/11-3 S

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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.
    35/11-3 S
    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
    Well name
    Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    35/11-3
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    MN 88 - 815 SP. 585
    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.
    Mobil Exploration Norway INC
    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.
    611-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.
    75
    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,
    27.06.1989
    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.
    09.09.1989
    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.
    09.09.1991
    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.
    15.06.2005
    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 SHOWS
    Discovery wellbore
    Indicator which tells if the wellbore made a new discovery. Legal values: YES, NO. Prior to press-release or other information regarding drilling results, the indicator will be “NO” as a default.
    NO
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    25.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    358.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4040.0
    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).
    4025.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    9.3
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    144
    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° 5' 12.24'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    3° 20' 18.47'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6772656.11
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    518257.03
    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.
    1356
  • Wellbore history

    General
    Well 35/11-3 S was drilled on a location ca 20 km north-north-east of the Troll Field, and was designed to test multiple deltaic sands in the Middle Jurassic Brent Group. Early Eocene turbidites and Paleocene channel fill deposits were secondary objectives. Reservoir sands were expected in the Tarbert, Ness, Etive and Oseberg Formations. These were hydrocarbon bearing in the 35/11-2 well. The seismic anomaly at Middle Jurassic level was mapped with a 30.4 km3 closure, and the expected gross thickness was 220 m. The site survey showed no strong indications of shallow gas. It was, however, thought possible that sands in the intervals 479 - 497 m, and 573 - 634 m might be gas charged.
    Operations and results
    Wildcat well 35/11-3 S was spudded with the semi-submersible installation Dyvi Stena on 27 June 1989 and drilled to TD at 4040 m in the Early Jurassic Statfjord Formation. The well was drilled deviated below 2100 m. Drilling proceeded without significant problems. However, the FMT sampling program for the Jurassic was curtailed when hole conditions deteriorated, and both the FMT tool and drill pipe became stuck during the final logging operation. The well was drilled with seawater and hi-vis pills down to 1010 m and with KCl/polymer mud from 1010 m to TD. No shallow gas was encountered.
    No reservoir rocks were encountered in the Lower Eocene succession, but good sands were present in the Paleocene (Intra Lista sand). Top Draupne Formation shales came in at 2821 m. Then came the Sognefjord Formation at 3081 m and the Heather Formation at 3096 m. The well penetrated the Brent Group at 3431 m, 236 m deep to prognosis. Good quality sands were found in the Brent Group, but not as good as in the 35/11-2 well.
    Gas levels throughout the Tertiary and Late Cretaceous were low. Oil shows with abundant free oil in the mud system were observed in limestones of the Early Cretaceous Rødby and Mime Formations and in sandstones of the Late Jurassic Sognefjord Formation. The sandstone units within the Middle Jurassic Brent Group were water wet with residual hydrocarbon shows. Petrophysical evaluation did not indicate hydrocarbons in the Cromer Knoll Group but did so in the Sognefjord Formation and, possibly, in the Brent Group. The evaluation and shows however, did not indicate significant hydrocarbons and did not warrant a test in any of the zones.
    Excellent, highly oil prone, source rock was found in the Draupne Formation and good source rock was found in the Heather Formation. Both are capable of producing large quantities of petroleum, given sufficient maturity. In well position the Draupne Formation is early mature for petroleum generation, but probably has not expelled any hydrocarbons yet. The Heather Formation appears early to middle mature and may have expelled significant oil quantities in the lower section. Maturity indicators show a dramatic increase in thermal maturity at the base of the Draupne Formation. A similar break is indicated in today temperature gradient in the wire line BHT data.
    Three conventional cores were cut: in the Intra Lista Sand, in the Sognefjord Formation, and in the Tarbert/Ness Formations of the Brent Group. FMT formation pressures were obtained in the Late Jurassic Sognefjord Formation and in the Brent and Dunlin Groups of the Middle and Early Jurassic. The valid pressure points showed a water gradient. Additionally, formation fluid samples were attempted in the Sognefjord Formation, but recovered only mud filtrate due to seal failures.
    The well was permanently abandoned on 9 September 1989 as a dry hole with oil shows.
    Testing
    No drill stem test was performed.
  • Cuttings at the Norwegian Offshore Directorate

    Cuttings at the Norwegian Offshore Directorate
    Cuttings available for sampling?
    YES
    Cuttings at the Norwegian Offshore Directorate
    Cutting sample, top depth [m]
    Cutting samples, bottom depth [m]
    1020.00
    4040.00
  • 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
    1987.0
    1996.0
    [m ]
    2
    3082.0
    3086.0
    [m ]
    3
    3446.0
    3472.8
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    39.8
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES
  • Core photos

    Core photos
    Core photo at depth: 1987-1992m
    Core photo at depth: 1992-1996m
    Core photo at depth: 3082-3086m
    Core photo at depth: 3446-3451m
    Core photo at depth: 3451-3456m
    1987-1992m
    1992-1996m
    3082-3086m
    3446-3451m
    3451-3456m
    Core photo at depth: 3456-3461m
    Core photo at depth: 3461-3466m
    Core photo at depth: 3466-3471m
    Core photo at depth: 3471-3472m
    Core photo at depth: 3085-3085m
    3456-3461m
    3461-3466m
    3466-3471m
    3471-3472m
    3085-3085m
    Core photo at depth: 3085-3085m
    Core photo at depth: 3085-2085m
    Core photo at depth: 3085-3085m
    Core photo at depth:  
    Core photo at depth:  
    3085-3085m
    3085-2085m
    3085-3085m
  • Palynological slides at the Norwegian Offshore Directorate

    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1020.0
    [m]
    DC
    RRI
    1050.0
    [m]
    SWC
    RRI
    1080.0
    [m]
    DC
    RRI
    1120.0
    [m]
    DC
    RRI
    1150.0
    [m]
    SWC
    RRI
    1180.0
    [m]
    DC
    RRI
    1220.0
    [m]
    DC
    RRI
    1280.0
    [m]
    DC
    RRI
    1320.0
    [m]
    DC
    RRI
    1350.0
    [m]
    SWC
    RRI
    1380.0
    [m]
    DC
    RRI
    1400.0
    [m]
    DC
    RRI
    1421.0
    [m]
    DC
    RRI
    1439.0
    [m]
    DC
    RRI
    1450.0
    [m]
    SWC
    RRI
    1469.0
    [m]
    DC
    RRI
    1481.0
    [m]
    DC
    RRI
    1511.0
    [m]
    SWC
    RRI
    1529.0
    [m]
    DC
    RRI
    1537.0
    [m]
    SWC
    RRI
    1550.0
    [m]
    DC
    RRI
    1610.0
    [m]
    DC
    RRI
    1619.0
    [m]
    DC
    RRI
    1620.0
    [m]
    DC
    RRI
    1650.0
    [m]
    SWC
    RRI
    1661.0
    [m]
    DC
    RRI
    1671.0
    [m]
    DC
    RRI
    1679.0
    [m]
    DC
    RRI
    1709.0
    [m]
    DC
    RRI
    1739.0
    [m]
    DC
    RRI
    1750.0
    [m]
    SWC
    RRI
    1775.0
    [m]
    SWC
    RRI
    1790.0
    [m]
    SWC
    RRI
    1799.0
    [m]
    DC
    RRI
    1811.0
    [m]
    DC
    RRI
    1825.0
    [m]
    SWC
    RRI
    1850.0
    [m]
    SWC
    RRI
    1910.0
    [m]
    SWC
    RRI
    2005.0
    [m]
    SWC
    RRI
    2009.0
    [m]
    DC
    RRI
    2051.0
    [m]
    DC
    RRI
    2550.0
    [m]
    SWC
    RRI
    2650.0
    [m]
    SWC
    RRI
    2690.0
    [m]
    SWC
    RRI
    2728.0
    [m]
    SWC
    RRI
    2800.0
    [m]
    DC
    RRI
    2805.0
    [m]
    DC
    RRI
    2815.0
    [m]
    DC
    RRI
    2820.0
    [m]
    DC
    RRI
    2840.0
    [m]
    DC
    RRI
    2880.0
    [m]
    SWC
    RRI
    2890.0
    [m]
    SWC
    RRI
    2910.0
    [m]
    SWC
    RRI
    2960.0
    [m]
    DC
    RRI
    3000.0
    [m]
    SWC
    RRI
    3025.0
    [m]
    DC
    RRI
    3030.0
    [m]
    DC
    RRI
    3040.0
    [m]
    DC
    RRI
    3070.0
    [m]
    SWC
    RRI
    3080.0
    [m]
    SWC
    RRI
    3082.0
    [m]
    C
    RRI
    3082.4
    [m]
    C
    RRI
    3082.7
    [m]
    C
    RRI
    3082.8
    [m]
    C
    HYDRO
    3083.4
    [m]
    C
    HYDRO
    3084.0
    [m]
    C
    RRI
    3084.4
    [m]
    C
    RRI
    3085.7
    [m]
    C
    RRI
    3100.0
    [m]
    SWC
    RRI
    3110.0
    [m]
    SWC
    RRI
    3120.0
    [m]
    SWC
    RRI
    3140.0
    [m]
    SWC
    RRI
    3170.0
    [m]
    DC
    RRI
    3180.0
    [m]
    SWC
    RRI
    3200.0
    [m]
    SWC
    RRI
    3220.0
    [m]
    SWC
    RRI
    3230.0
    [m]
    DC
    RRI
    3240.0
    [m]
    SWC
    RRI
    3260.0
    [m]
    SWC
    RRI
    3280.0
    [m]
    SWC
    RRI
    3290.0
    [m]
    DC
    RRI
    3300.0
    [m]
    SWC
    RRI
    3310.0
    [m]
    DC
    RRI
    3320.0
    [m]
    SWC
    RRI
    3360.0
    [m]
    SWC
    RRI
    3380.0
    [m]
    SWC
    RRI
    3400.0
    [m]
    SWC
    RRI
    3410.0
    [m]
    DC
    RRI
    3420.0
    [m]
    SWC
    RRI
    3430.0
    [m]
    DC
    RRI
    3443.5
    [m]
    SWC
    RRI
    3446.5
    [m]
    C
    RRI
    3454.6
    [m]
    C
    RRI
    3458.6
    [m]
    C
    RRI
    3462.6
    [m]
    C
    RRI
    3467.7
    [m]
    C
    RRI
    3472.7
    [m]
    C
    RRI
    3477.0
    [m]
    SWC
    RRI
    3494.0
    [m]
    SWC
    RRI
    3505.5
    [m]
    SWC
    RRI
    3522.0
    [m]
    SWC
    RRI
    3589.0
    [m]
    SWC
    RRI
    3609.0
    [m]
    SWC
    RRI
    3640.0
    [m]
    DC
    RRI
    3650.0
    [m]
    DC
    RRI
    3660.0
    [m]
    DC
    RRI
    3670.0
    [m]
    DC
    RRI
    3710.0
    [m]
    DC
    RRI
    3730.0
    [m]
    DC
    RRI
    3760.0
    [m]
    DC
    RRI
    3790.0
    [m]
    DC
    RRI
    3830.0
    [m]
    DC
    RRI
    3850.0
    [m]
    DC
    RRI
    3900.0
    [m]
    DC
    RRI
    3920.0
    [m]
    DC
    RRI
    4000.0
    [m]
    DC
    RRI
  • Lithostratigraphy

  • Composite logs

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

    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    2.95
  • 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
    41.29
  • Logs

    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    ACBL VDL GR
    875
    3038
    ACBL VDR GR
    1610
    2175
    COREGUN GR
    1050
    2028
    COREGUN GR
    1690
    1975
    COREGUN GR
    2100
    3110
    COREGUN GR
    2100
    3110
    COREGUN GR
    3120
    3745
    DIFL AC GR
    998
    4042
    DIPLOG GR
    998
    2034
    DIPLOG GR
    3116
    3700
    FMT GR
    2717
    3095
    FMT GR
    3453
    3497
    FMT GR
    3469
    3695
    MWD - GR RES DIR
    499
    4040
    VSP
    1780
    3870
    ZDEN CNL GR CAL
    998
    4041
  • 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
    498.0
    36
    499.0
    0.00
    LOT
    INTERM.
    20
    1000.0
    26
    1013.0
    1.42
    LOT
    INTERM.
    13 3/8
    2040.0
    17 1/2
    2057.0
    1.70
    LOT
    INTERM.
    9 5/8
    3111.0
    12 1/4
    3115.0
    1.91
    LOT
    OPEN HOLE
    4040.0
    8 1/2
    4040.0
    0.00
    LOT
  • Drilling mud

    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    400
    1.03
    WATER BASED
    30.06.1989
    499
    1.03
    WATER BASED
    03.07.1989
    692
    1.03
    WATER BASED
    04.07.1989
    1010
    1.03
    WATER BASED
    04.07.1989
    1010
    1.03
    WATER BASED
    04.07.1989
    1010
    1.03
    WATER BASED
    10.07.1989
    1010
    1.03
    WATER BASED
    04.07.1989
    1010
    1.03
    WATER BASED
    10.07.1989
    1285
    1.20
    17.0
    21.0
    WATER BASED
    18.07.1989
    1554
    1.02
    21.0
    20.0
    WATER BASED
    18.07.1989
    1761
    1.20
    21.0
    20.0
    WATER BASED
    18.07.1989
    1776
    1.20
    16.0
    20.0
    WATER BASED
    18.07.1989
    1987
    1.20
    17.0
    21.0
    WATER BASED
    18.07.1989
    1996
    1.20
    16.0
    21.0
    WATER BASED
    18.07.1989
    2039
    1.27
    16.0
    19.0
    WATER BASED
    18.07.1989
    2057
    1.27
    14.0
    16.0
    WATER BASED
    18.07.1989
    2057
    1.27
    14.0
    16.0
    WATER BASED
    18.07.1989
    2070
    1.03
    15.0
    24.0
    WATER BASED
    24.07.1989
    2120
    1.30
    21.0
    21.0
    WATER BASED
    25.07.1989
    2224
    1.30
    24.0
    26.0
    WATER BASED
    26.07.1989
    2278
    1.30
    20.0
    24.0
    WATER BASED
    28.07.1989
    2366
    1.26
    18.0
    22.0
    WATER BASED
    31.07.1989
    2467
    1.26
    18.0
    26.0
    WATER BASED
    31.07.1989
    2531
    1.26
    16.0
    23.0
    WATER BASED
    01.08.1989
    2622
    1.26
    16.0
    18.0
    WATER BASED
    01.08.1989
    2701
    1.26
    17.0
    22.0
    WATER BASED
    02.08.1989
    2726
    1.26
    16.0
    18.0
    WATER BASED
    03.08.1989
    2775
    1.26
    15.0
    18.0
    WATER BASED
    07.08.1989
    3039
    1.26
    17.0
    18.0
    WATER BASED
    07.08.1989
    3082
    1.38
    18.0
    20.0
    WATER BASED
    07.08.1989
    3096
    1.38
    18.0
    23.0
    WATER BASED
    08.08.1989
    3115
    1.38
    17.0
    19.0
    WATER BASED
    08.08.1989
    3204
    1.62
    28.0
    18.0
    WATER BASED
    17.08.1989
    3333
    1.62
    22.0
    16.0
    WATER BASED
    22.08.1989
    3352
    1.62
    21.0
    17.0
    WATER BASED
    22.08.1989
    3446
    1.62
    23.0
    16.0
    WATER BASED
    22.08.1989
    3673
    1.58
    24.0
    15.0
    WATER BASED
    24.08.1989
    3673
    1.58
    25.0
    17.0
    WATER BASED
    28.08.1989
    3673
    1.58
    24.0
    15.0
    WATER BASED
    24.08.1989
    3891
    1.58
    25.0
    17.0
    WATER BASED
    28.08.1989
    3910
    1.58
    32.0
    23.0
    WATER BASED
    28.08.1989
    3929
    1.58
    25.0
    18.0
    WATER BASED
    28.08.1989
    4040
    1.40
    21.0
    17.0
    WATER BASED
    04.09.1989
    4040
    1.58
    32.0
    24.0
    WATER BASED
    31.08.1989
    4040
    1.49
    35.0
    15.0
    WATER BASED
    04.09.1989
    4040
    1.40
    20.0
    19.0
    WATER BASED
    05.09.1989
  • 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