Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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15.07.2024 - 01:28
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2/1-8

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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.
    2/1-8
    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.
    2/1-8
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    BP 80 - 37 SP. 400
    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.
    BP Norway Limited U.A.
    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.
    473-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.
    119
    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,
    28.07.1985
    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.
    23.11.1985
    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.
    23.11.1987
    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.
    12.03.2011
    Purpose - planned
    Pre-drill purpose of the wellbore. Legal values for exploration wellbores: WILDCAT, APPRAISAL, WILDCAT-CCS, APPRAISAL-CCS. Example of legal values for development wellbores: OBSERVATION, PRODUCTION, INJECTION.
    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.
    LATE 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.
    ULA FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    37.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    66.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4151.0
    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).
    4146.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    6
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    160
    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.
    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.
    SKAGERRAK FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    56° 53' 40.63'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    3° 6' 55.95'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6305802.54
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    507039.08
    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.
    459
  • Wellbore history

    General
    Well 2/1-8 was drilled on the Cod Terrace on the margin between the southern Vestland Arch and the Central Trough in the North Sea. The objective was to evaluate the Late Jurassic Gyda member reservoir sandstone (the "2/1-3 Sand") in the south-eastern part of the field.
    Operations and results
    Appraisal well 2/1-8 was spudded with the jack-up installation Neddrill Trigon on 28 July 1985 and drilled to TD at 4151 m (4159 m Logger's Depth) in the Triassic Skagerrak Formation. The well was drilled with spud mud down to 635 m, and with KCl/polymer mud from 635 m to 3474 m. At this depth the drill string got stuck while pulling out of the hole. It was freed after pumping pipelax into the hole. Following the pipelax pill and down to 3888 m the mud contained 1.0 - 2.5% oil. Drilling commenced with an oil-free KCl/polymer mud from 3888 m to TD. Below 2000 m logger's depth = driller's depth + 8 m. Above this depth there is no discrepancy. In the following all quoted depths are logger's depths.
    A 40 m thick Gyda member sandstone was penetrated at a depth of 3899.5 m. Cores from the reservoir proved a coarsening up sequence of very fine to medium grained sandstone. The reservoir was oil bearing throughout. Oil stain and gas bleed were observed in cores of very fine sandstones and siltstones from the underlying Farsund and Haugesund Formations. The Ula Formation at 4037 m was 26 m thick and water bearing. Traces of hydrocarbons were recorded from 3818 - 3821 m in the Early Cretaceous Åsgard Formation. These possibly result from leakage, up a minor fault, from Late Jurassic rocks. There were no significant hydrocarbon shows in any other section of the well.
    Three cores were cut in the Late Jurassic Gyda member, Farsund Formation, and Haugesund Formation, from 3906.0 to 3989.3 m with 95 to 100 % recovery. The RFT tool was run for pressure points, but no wire line fluid samples were taken.
    The well was permanently abandoned on 23 November 1985 as an oil appraisal well.
    Testing
    Two drill stem tests were carried out in the Gyda member sandstone
    DST1A tested the interval 3919 to 3926 m. This test was designed to evaluate the lower part of the reservoir; however it is thought that communication vas established behind casing with more permeable higher zones. Thus the results are unreliable. The test produced oil at a maximum rate of 1950 Sm3/day through a 16/64" choke. Oil gravity was 39.8 deg API and GOR was 633 Sm3/Sm3. The maximum flowing bottom hole temperature measured in the test was 154 deg C.
    DST1B tested the interval 3900.5-3926 m. Dry oil was produced at a maximum rate of 1010 Sm3/day through a 28/64" fixed choke. The oil gravity was 40 deg API and the GOR was 665 Sm3/Sm3.
  • 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]
    190.00
    4152.00
  • 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
    3898.0
    3924.0
    [m ]
    2
    3925.8
    3931.0
    [m ]
    3
    3953.0
    3981.3
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    59.5
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES
  • Core photos

    Core photos
    Core photo at depth: 3898-3903m
    Core photo at depth: 3903-3908m
    Core photo at depth: 3908-3913m
    Core photo at depth: 3913-3918m
    Core photo at depth: 3918-3923m
    3898-3903m
    3903-3908m
    3908-3913m
    3913-3918m
    3918-3923m
    Core photo at depth: 3923-3924m
    Core photo at depth: 3925-3930m
    Core photo at depth: 3930-3935m
    Core photo at depth: 3935-3940m
    Core photo at depth: 3940-3945m
    3923-3924m
    3925-3930m
    3930-3935m
    3935-3940m
    3940-3945m
    Core photo at depth: 3945-3950m
    Core photo at depth: 3950-3953m
    Core photo at depth: 3953-3958m
    Core photo at depth: 3958-3963m
    Core photo at depth: 3963-3968m
    3945-3950m
    3950-3953m
    3953-3958m
    3958-3963m
    3963-3968m
    Core photo at depth: 3968-3973m
    Core photo at depth: 3973-3978m
    Core photo at depth: 3978-3981m
    Core photo at depth:  
    Core photo at depth:  
    3968-3973m
    3973-3978m
    3978-3981m
  • Palynological slides at the Norwegian Offshore Directorate

    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    3890.1
    [m]
    C
    APT
    3898.2
    [m]
    C
    APT
    3900.0
    [m]
    C
    APT
    3901.8
    [m]
    C
    APT
    3901.9
    [m]
    C
    APT
    3902.9
    [m]
    C
    APT
    3903.4
    [m]
    C
    APT
    3904.9
    [m]
    C
    APT
    3905.6
    [m]
    C
    APT
    3907.5
    [m]
    C
    APT
    3909.7
    [m]
    C
    APT
    3910.7
    [m]
    C
    APT
    3912.7
    [m]
    C
    APT
    3914.3
    [m]
    C
    APT
    3916.4
    [m]
    C
    APT
    3919.5
    [m]
    C
    APT
    3921.4
    [m]
    C
    APT
    3923.4
    [m]
    C
    APT
    3926.4
    [m]
    C
    APT
    3928.4
    [m]
    C
    APT
    3930.4
    [m]
    C
    APT
    3932.4
    [m]
    C
    APT
    3934.4
    [m]
    C
    APT
    3936.4
    [m]
    C
    APT
    3938.4
    [m]
    C
    APT
    3940.4
    [m]
    C
    APT
    3942.4
    [m]
    C
    APT
    3946.4
    [m]
    C
    APT
    3948.4
    [m]
    C
    APT
    3950.4
    [m]
    C
    APT
    3952.4
    [m]
    C
    APT
    3954.4
    [m]
    C
    APT
    3956.4
    [m]
    C
    APT
    3958.4
    [m]
    C
    APT
    3960.4
    [m]
    C
    APT
    3962.4
    [m]
    C
    APT
    3962.4
    [m]
    C
    APT
    3964.4
    [m]
    C
    APT
    3968.4
    [m]
    C
    APT
    3970.4
    [m]
    C
    APT
    3972.4
    [m]
    C
    APT
    3974.4
    [m]
    C
    APT
    3976.4
    [m]
    C
    APT
    3978.4
    [m]
    C
    APT
    3980.4
    [m]
    C
    APT
    3981.4
    [m]
    C
    APT
    3990.0
    [m]
    DC
    APT
    3996.0
    [m]
    DC
    APT
    3999.0
    [m]
    DC
    APT
    4002.0
    [m]
    DC
    APT
    4005.0
    [m]
    DC
    APT
    4008.0
    [m]
    DC
    APT
    4011.0
    [m]
    DC
    APT
    4014.0
    [m]
    DC
    APT
    4017.0
    [m]
    DC
    APT
    4020.0
    [m]
    DC
    APT
    4023.0
    [m]
    DC
    APT
    4026.0
    [m]
    DC
    APT
    4029.0
    [m]
    DC
    APT
    4032.0
    [m]
    DC
    APT
    4035.0
    [m]
    DC
    APT
    4038.0
    [m]
    DC
    APT
    4041.0
    [m]
    DC
    APT
    4044.0
    [m]
    DC
    APT
    4047.0
    [m]
    DC
    APT
    4050.0
    [m]
    DC
    APT
    4053.0
    [m]
    DC
    APT
    4056.0
    [m]
    DC
    APT
    4059.0
    [m]
    DC
    APT
    4062.0
    [m]
    DC
    APT
    4065.0
    [m]
    DC
    APT
  • Lithostratigraphy

  • Composite logs

    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.69
  • Geochemical information

    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    1.09
    pdf
    0.75
    pdf
    0.19
  • 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
    2.96
    pdf
    6.76
  • Drill stem tests (DST)

    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    3919
    3926
    6.4
    2.0
    3901
    3926
    11.1
    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
    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
    305
    0.826
    0.740
    99
    2.0
    954
    0.825
    0.825
    107
  • Logs

    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL VDL GR
    50
    2000
    CST GR
    3890
    4141
    CYBERDIP
    3887
    4155
    CYBERLOOK
    3890
    4145
    DLL MAFL GR CAL
    3887
    4159
    GR SP
    3600
    3832
    HP RFT GR
    3902
    4140
    ISF BHC GR SP
    3877
    4159
    ISF BHC MAFL GR CAL SP
    2000
    3895
    ISF LSS GR SP
    193
    633
    ISF LSS MSFL GR CAL SP
    625
    2003
    LDL CNL NGL CAL
    3887
    4159
    NGL SP
    3887
    4159
    SHDT GR
    3887
    4155
  • 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
    193.0
    36
    193.0
    0.00
    LOT
    SURF.COND.
    20
    625.0
    26
    635.0
    1.76
    LOT
    INTERM.
    13 3/8
    2000.0
    17 1/2
    2005.0
    2.04
    LOT
    INTERM.
    9 5/8
    3888.0
    12 1/4
    3898.0
    2.12
    LOT
    OPEN HOLE
    4158.0
    8 1/2
    4158.0
    0.00
    LOT
  • Drilling mud

    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    139
    1.08
    100.0
    WATER BASED
    29.07.1985
    183
    1.08
    WATER BASED
    29.07.1985
    188
    1.06
    19.0
    WATER BASED
    05.08.1985
    215
    1.06
    20.0
    16.0
    WATER BASED
    05.08.1985
    373
    1.09
    15.0
    15.0
    WATER BASED
    05.08.1985
    536
    1.09
    20.0
    19.0
    WATER BASED
    07.08.1985
    635
    1.12
    17.0
    17.0
    WATER BASED
    08.08.1985
    640
    1.18
    28.0
    5.8
    WATER BASED
    08.08.1985
    920
    1.23
    23.0
    5.8
    WATER BASED
    13.08.1985
    1115
    1.28
    22.0
    5.8
    WATER BASED
    12.08.1985
    1280
    1.30
    23.0
    6.2
    WATER BASED
    13.08.1985
    1429
    1.33
    22.0
    5.8
    WATER BASED
    15.08.1985
    1632
    1.35
    25.0
    5.8
    WATER BASED
    19.08.1985
    1788
    1.41
    23.0
    5.8
    WATER BASED
    19.08.1985
    1788
    1.50
    21.0
    6.2
    WATER BASED
    19.08.1985
    1817
    1.50
    25.0
    6.2
    WATER BASED
    17.08.1985
    1971
    1.56
    30.0
    6.7
    WATER BASED
    21.08.1985
    2000
    1.58
    27.5
    5.3
    WATER BASED
    18.09.1985
    2005
    1.57
    27.0
    4.8
    WATER BASED
    26.08.1985
    2005
    1.56
    23.0
    7.2
    WATER BASED
    21.08.1985
    2005
    1.58
    31.0
    6.2
    WATER BASED
    23.08.1985
    2005
    1.59
    3531.0
    76.2
    WATER BASED
    26.08.1985
    2005
    1.59
    35.0
    7.2
    WATER BASED
    26.08.1985
    2005
    1.56
    28.0
    4.8
    WATER BASED
    26.08.1985
    2005
    1.56
    27.0
    4.3
    WATER BASED
    27.08.1985
    2005
    1.56
    37.0
    11.5
    WATER BASED
    29.08.1985
    2005
    1.57
    20.0
    3.8
    WATER BASED
    02.09.1985
    2005
    1.58
    38.0
    11.5
    WATER BASED
    02.09.1985
    2009
    1.58
    34.0
    8.6
    WATER BASED
    02.09.1985
    2345
    1.58
    37.0
    7.7
    WATER BASED
    03.09.1985
    2365
    1.59
    37.0
    7.2
    WATER BASED
    04.09.1985
    2509
    1.58
    37.0
    6.7
    WATER BASED
    05.09.1985
    2706
    1.58
    35.0
    7.7
    WATER BASED
    06.09.1985
    2878
    1.58
    37.0
    11.0
    WATER BASED
    09.09.1985
    2894
    1.58
    27.0
    5.8
    WATER BASED
    09.09.1985
    2952
    1.58
    17.0
    5.8
    WATER BASED
    09.09.1985
    2994
    1.58
    36.0
    7.7
    WATER BASED
    10.09.1985
    3000
    1.58
    30.0
    7.2
    WATER BASED
    11.09.1985
    3095
    1.58
    35.0
    9.6
    WATER BASED
    12.09.1985
    3171
    1.58
    24.0
    6.7
    WATER BASED
    13.09.1985
    3196
    1.58
    24.5
    9.1
    WATER BASED
    16.09.1985
    3222
    1.58
    21.0
    4.8
    WATER BASED
    16.09.1985
    3254
    1.58
    24.5
    5.3
    WATER BASED
    16.09.1985
    3344
    1.58
    27.0
    5.8
    WATER BASED
    17.09.1985
    3432
    1.58
    22.5
    5.3
    WATER BASED
    19.09.1985
    3578
    1.58
    26.0
    4.8
    WATER BASED
    20.09.1985
    3602
    1.61
    35.0
    7.2
    WATER BASED
    18.11.1985
    3660
    1.60
    27.0
    6.2
    WATER BASED
    23.09.1985
    3723
    1.62
    32.5
    7.2
    WATER BASED
    23.09.1985
    3723
    1.62
    37.5
    6.2
    WATER BASED
    23.09.1985
    3723
    1.62
    29.0
    5.8
    WATER BASED
    24.09.1985
    3723
    1.61
    23.0
    4.8
    WATER BASED
    25.09.1985
    3736
    1.62
    31.0
    6.7
    WATER BASED
    26.09.1985
    3775
    1.62
    37.0
    6.7
    WATER BASED
    27.09.1985
    3816
    1.62
    41.0
    8.6
    WATER BASED
    30.09.1985
    3832
    1.64
    38.0
    7.2
    WATER BASED
    30.09.1985
    3844
    1.64
    37.0
    7.2
    WATER BASED
    01.10.1985
    3884
    1.64
    35.0
    7.7
    WATER BASED
    01.10.1985
    3888
    1.68
    32.0
    5.8
    WATER BASED
    02.10.1985
    3888
    1.69
    33.0
    6.2
    WATER BASED
    07.10.1985
    3888
    1.69
    30.5
    6.2
    WATER BASED
    08.10.1985
    3888
    1.69
    32.5
    7.2
    WATER BASED
    08.10.1985
    3898
    1.56
    24.5
    6.2
    WATER BASED
    08.10.1985
    3926
    1.56
    24.0
    5.8
    WATER BASED
    09.10.1985
    3954
    1.56
    25.0
    5.8
    WATER BASED
    09.10.1985
    3981
    1.56
    29.0
    6.7
    WATER BASED
    10.10.1985
    4015
    1.56
    35.0
    7.7
    WATER BASED
    11.10.1985
    4051
    1.56
    33.5
    7.2
    WATER BASED
    14.10.1985
    4092
    1.56
    30.0
    6.7
    WATER BASED
    14.10.1985
    4151
    1.57
    29.0
    5.8
    WATER BASED
    14.10.1985
    4151
    1.57
    26.5
    5.3
    WATER BASED
    15.10.1985
    4151
    1.57
    26.5
    5.3
    WATER BASED
    16.10.1985
    4151
    1.57
    26.5
    5.3
    WATER BASED
    17.10.1985
    4151
    1.57
    25.5
    5.1
    WATER BASED
    18.10.1985
    4151
    1.58
    24.0
    5.8
    WATER BASED
    21.10.1985
    4151
    1.58
    23.0
    5.8
    WATER BASED
    21.10.1985
    4151
    1.58
    22.0
    5.3
    WATER BASED
    21.10.1985
    4151
    1.57
    23.0
    6.7
    WATER BASED
    22.10.1985
    4151
    1.57
    22.0
    6.7
    WATER BASED
    23.10.1985
    4151
    1.56
    20.0
    3.8
    WATER BASED
    29.10.1985
    4151
    1.55
    18.0
    4.8
    WATER BASED
    29.10.1985
    4151
    1.57
    17.0
    4.3
    WATER BASED
    29.10.1985
    4151
    1.60
    30.0
    8.2
    WATER BASED
    29.10.1985
    4151
    1.60
    30.0
    8.2
    WATER BASED
    31.10.1985
    4151
    1.60
    30.0
    8.6
    WATER BASED
    01.11.1985
    4151
    1.60
    32.0
    9.1
    WATER BASED
    01.11.1985
    4151
    1.60
    34.0
    10.6
    WATER BASED
    04.11.1985
    4151
    1.60
    32.0
    9.1
    WATER BASED
    05.11.1985
    4151
    1.60
    9.1
    WATER BASED
    07.11.1985
    4151
    1.60
    32.0
    8.6
    WATER BASED
    07.11.1985
    4151
    1.60
    32.0
    8.6
    WATER BASED
    11.11.1985
    4151
    1.60
    29.5
    9.1
    WATER BASED
    11.11.1985
    4151
    1.60
    31.0
    8.6
    WATER BASED
    11.11.1985
    4151
    1.60
    34.0
    9.6
    WATER BASED
    11.11.1985
    4151
    1.60
    38.0
    9.6
    WATER BASED
    12.11.1985
    4151
    1.60
    35.0
    7.2
    WATER BASED
    18.11.1985
    4151
    1.57
    26.0
    6.2
    WATER BASED
    21.10.1985
    4151
    1.55
    20.0
    5.8
    WATER BASED
    24.10.1985
    4151
    1.55
    20.0
    5.8
    WATER BASED
    29.10.1985
    4151
    1.61
    27.0
    7.2
    WATER BASED
    01.11.1985
    4151
    1.60
    38.0
    9.6
    WATER BASED
    18.11.1985
  • 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]
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    0.22