Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no          Norsk
15.07.2024 - 01:28
Time of last synchronization with Norwegian Offshore Directorate's internal systems

30/6-23

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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.
    30/6-23
    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.
    SUSPENDED
    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.
    30/6-23
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    NH 8606- ROW 548 & CDP NO 729
    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.
    634-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.
    64
    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,
    29.04.1990
    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.
    01.07.1990
    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.
    01.07.1992
    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.
    29.03.2014
    Purpose - planned
    Pre-drill purpose of the wellbore. Legal values for exploration wellbores: WILDCAT, APPRAISAL, WILDCAT-CCS, APPRAISAL-CCS. Example of legal values for development wellbores: OBSERVATION, PRODUCTION, INJECTION.
    APPRAISAL
    Reentry
    Status whether the wellbore has been re-entered (YES) or not (NO). Re-entered wellbores are not included in the count when wellbores are presented in statistical overviews.
    NO
    Content
    For exploration wellbores, status of discovery.

    Legal values:
    DRY, SHOWS (trace amounts of hydrocarbons), GAS, GAS/CONDENSATE, OIL or OIL/GAS.
    SHOWS (GAS SHOWS, OIL SHOWS or OIL/GAS SHOWS) are detected as fluorescent cut (organic extract), petroleum odour, or visual stain on cuttings or cores, or as increased gas reading on the mud-loggers gas detection equipment.
    Legal values for WILDCAT-CCS and APPRAISAL-CCS: WATER

    For development wellbores, type of produced/injected fluid.
    Legal values:
    WATER, CUTTINGS, NOT AVAILABLE, OIL, GAS/CONDENSATE, OIL/GAS, CO2, GAS, WATER/GAS, NOT APPLICABLE.
    OIL
    Discovery wellbore
    Indicator which tells if the wellbore made a new discovery. Legal values: YES, NO. Prior to press-release or other information regarding drilling results, the indicator will be “NO” as a default.
    NO
    1st level with HC, age
    Age of lithostratigraphic unit, 1st level, where hydrocarbons were encountered. Examples of legal values: CRETACEOUS, EARLY CRETACEOUS, LATE JURASSIC, EOCENE. See also Norwegian Offshore Directorate bulletins.
    MIDDLE JURASSIC
    1st level with HC, formation
    Name of lithostartigraphic unit, 1st level, where hydrocarbons were encountered. Shown only for released wells. Examples of legal values: BASEMENT, COOK FM, EKOFISK FM, HEIMDAL FM, SANDNES FM, SOGNEFJORD FM, TARBERT FM, BRENT GP. See also Norwegian Offshore Directorate bulletins.
    BRENT GP
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    23.5
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    152.5
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3209.5
    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).
    3208.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    3.7
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    133
    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.
    EIRIKSSON FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    60° 40' 58.01'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 55' 58.97'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6727615.50
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    496342.56
    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.
    1545
  • Wellbore history

    General
    Well 30/6-23 was drilled on the Beta South structure on the Brage Horst and south of the Veslefrikk Field in the North Sea. The Beta structure is surrounded by producing oil fields or commercial discoveries. On Beta, oil has been discovered in the Middle Jurassic Brent Group reservoirs in fault-block traps. The oil is contained in two main sub-structures, i.e. the Beta Saddle and Beta South, comprising several smaller sub-compartments. The discovery well on Beta was the 30/6-5 well, but this well was not tested due to the detection of H2S in the RFT samples. Later wells proved oil in the Beta Saddle without encountering H2S. The Beta Saddle is characterized by a multicontact reservoir having prominent shale barriers. There are also slight differences in fluid composition between the two compartments, which suggests that the saddle through is acting as a structural spill point at the top Etive level. Primary target for the well was Base Brent Group prognosed to come in at 2891 m. Secondary objective was top Statfjord prognosed at 3141 m. OWC was expected at 2880 m.
    Operations and results
    Appraisal well 30/6-23 was spudded 29 April 1990 by the semi-submersible rig Transocean 8 and drilled to TD at 3209.5 m in the Early Jurassic Eirikson Formation. Shallow gas was indicated from mud gas and MWD at several levels between 440 m and 603 m. Gas influx occurred during a wiper trip back from 601 m to the 30" casing shoe at 261 m. Otherwise drilling proceeded without any significant issues. The well was drilled with spud mud down to 378 m and with KCl/polymer mud from 378 m to TD.
    Formation tops came in approximately as prognosed. Top Viking Group was encountered 2534 m and consisted of 82 m Draupne Formation and 177 m Heather Formation. The target Brent Group came in at 2793 m and oil was proven in sandstones by logs, RFT pressure gradient and tests all through. No clear OWC was encountered, but good oil shows were seen in a sandstone as deep as 2896 m at the base of the Oseberg Formation. The Statfjord Formation was water bearing.
    Six cores were cut: five in the interval 2787 to 2902 m in the Brent Group and one at 3018 to 3045 m in the Cook Formation. Good shows were recorded in cores 1 to 5, but core 6 (Cook Formation) displayed only weak shows on single sand grains. Segregated RFT samples were taken at 2843 m, 2871.5 m, 2899.5 m, 3016.5 m, and 3177.5 m.
    The well was suspended on 1 July 1990 as an oil appraisal well.
    Testing
    Three DST tests were performed.
    DST 1 tested the interval 2860 - 2881 m in the middle Oseberg formation. It produced 1375 Sm3 oil and 74500 Sm3 gas /day through a 25.4 mm choke. The separator GOR was 54 Sm3/Sm3 and the oil density was 0.840 g/cm3. The maximum flowing temperature measured at sensor depth 2761.4 m was 120.6 deg C.
    DST 2 tested the interval 2827 - 2853 m in the upper Oseberg/Etive formations. It produced 849 Sm3 oil and 56500 Sm3 gas /day through a 60.64 mm choke. The separator GOR was 66 Sm3/Sm3 and the oil density was 0.840 g/cm3. The maximum flowing temperature measured at sensor depth 2755.7 m was 120.1 deg C.
    DST 3 tested the interval 2803 - 2812 m in the Ness formation. It produced 1040 Sm3 oil and 64200 Sm3 gas /day through a 20.64 mm choke. The separator GOR was 62 Sm3/Sm3 and the oil density was 0.840 g/cm3. The maximum flowing temperature measured at sensor depth 2750.8 m was 120.8 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]
    430.00
    3210.00
  • 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
    2787.0
    2813.7
    [m ]
    2
    2814.0
    2821.5
    [m ]
    3
    2822.3
    2850.0
    [m ]
    4
    2850.0
    2868.5
    [m ]
    5
    2869.0
    2902.0
    [m ]
    6
    3018.0
    3045.0
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    140.5
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES
  • Core photos

    Core photos
    Core photo at depth: 2787-2792m
    Core photo at depth: 2792-2797m
    Core photo at depth: 2797-2802m
    Core photo at depth: 2802-2907m
    Core photo at depth: 2807-2812m
    2787-2792m
    2792-2797m
    2797-2802m
    2802-2907m
    2807-2812m
    Core photo at depth: 2812-2813m
    Core photo at depth: 2814-2819m
    Core photo at depth: 2819-2821m
    Core photo at depth: 2822-2827m
    Core photo at depth: 2827-2832m
    2812-2813m
    2814-2819m
    2819-2821m
    2822-2827m
    2827-2832m
    Core photo at depth: 2832-2837m
    Core photo at depth: 2837-2842m
    Core photo at depth: 2842-2847m
    Core photo at depth: 2847-2850m
    Core photo at depth: 2850-2855m
    2832-2837m
    2837-2842m
    2842-2847m
    2847-2850m
    2850-2855m
    Core photo at depth: 2855-2860m
    Core photo at depth: 2860-2865m
    Core photo at depth: 2865-2868m
    Core photo at depth: 2859-2874m
    Core photo at depth: 2874-2879m
    2855-2860m
    2860-2865m
    2865-2868m
    2859-2874m
    2874-2879m
    Core photo at depth: 2879-2884m
    Core photo at depth: 2884-2889m
    Core photo at depth: 2889-2894m
    Core photo at depth: 2894-2899m
    Core photo at depth: 2899-2902m
    2879-2884m
    2884-2889m
    2889-2894m
    2894-2899m
    2899-2902m
    Core photo at depth: 3018-3023m
    Core photo at depth: 3023-3028m
    Core photo at depth: 3028-3033m
    Core photo at depth: 3033-3038m
    Core photo at depth: 3038-3043m
    3018-3023m
    3023-3028m
    3028-3033m
    3033-3038m
    3038-3043m
    Core photo at depth: 3043-3045m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    3043-3045m
  • Palynological slides at the Norwegian Offshore Directorate

    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    2787.0
    [m]
    C
    RRI
    2788.0
    [m]
    C
    RRI
    2828.0
    [m]
    C
    RRI
    2833.0
    [m]
    C
    RRI
    2835.0
    [m]
    C
    RRI
    2849.0
    [m]
    C
    RRI
    2851.0
    [m]
    C
    RRI
    2854.0
    [m]
    C
    RRI
    2857.0
    [m]
    C
    RRI
    2877.0
    [m]
    C
    RRI
    2879.0
    [m]
    C
    RRI
    2882.0
    [m]
    C
    RRI
    2886.0
    [m]
    C
    RRI
    2890.0
    [m]
    C
    RRI
    2893.0
    [m]
    C
    RRI
    2896.0
    [m]
    C
    RRI
    2900.0
    [m]
    C
    RRI
  • 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
    2860.00
    2881.00
    YES
    DST
    DST2
    2827.00
    2853.00
    18.06.1990 - 00:00
    YES
    DST
    DST3
    2803.00
    2812.00
    21.06.1990 - 17:16
    YES
  • Lithostratigraphy

  • Documents – reported by the production licence (period for duty of secrecy expired)

    Documents – reported by the production licence (period for duty of secrecy expired)
    Document name
    Document format
    Document size [MB]
    pdf
    14.39
  • Drill stem tests (DST)

    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    2860
    2881
    25.4
    2.0
    2827
    2853
    20.4
    3.0
    2803
    2812
    20.4
    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
    1575
    74200
    0.840
    47
    2.0
    849
    56500
    0.840
    66
    3.0
    1040
    64200
    0.840
    62
  • Logs

    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    BHC
    951
    2689
    CBL VDL GR
    173
    951
    DIL LSS LDT GR
    725
    2690
    DITE LSS LDL CNL GR AMS
    857
    117
    DITE SDT LDT CNT GR CAL
    2690
    3211
    DLL MSFL GR
    2690
    3211
    FMS
    2690
    2970
    MWD
    174
    3210
    RFT
    2806
    2806
    RFT
    2843
    2843
    RFT
    2871
    2871
    RFT
    2899
    2899
    RFT
    3016
    3016
    RFT
    3177
    3177
    VSP
    900
    3140
  • 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
    261.0
    36
    262.0
    0.00
    LOT
    INTERM.
    20
    372.0
    26
    601.0
    0.00
    LOT
    INTERM.
    13 3/8
    950.0
    17 1/2
    965.0
    1.65
    LOT
    INTERM.
    9 5/8
    2689.0
    12 1/4
    2704.0
    1.75
    LOT
    LINER
    7
    3208.0
    8 1/2
    3210.0
    0.00
    LOT
  • Drilling mud

    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    378
    1.20
    WATER BASED
    03.05.1990
    378
    1.20
    WATER BASED
    04.05.1990
    378
    1.15
    WATER BASED
    10.05.1990
    380
    1.22
    17.0
    11.0
    WATER BASED
    02.07.1990
    607
    1.17
    13.0
    7.0
    WATER BASED
    10.05.1990
    950
    1.18
    17.0
    10.0
    WATER BASED
    10.05.1990
    965
    1.18
    18.0
    11.0
    WATER BASED
    10.05.1990
    965
    1.18
    19.0
    12.0
    WATER BASED
    10.05.1990
    965
    1.18
    17.0
    10.0
    WATER BASED
    10.05.1990
    1012
    1.18
    19.0
    12.0
    WATER BASED
    14.05.1990
    1356
    1.40
    25.0
    14.0
    WATER BASED
    14.05.1990
    1614
    1.40
    21.0
    14.0
    WATER BASED
    14.05.1990
    1987
    1.40
    22.0
    15.0
    WATER BASED
    14.05.1990
    2167
    1.40
    23.0
    17.0
    WATER BASED
    15.05.1990
    2260
    1.40
    24.0
    13.0
    WATER BASED
    16.05.1990
    2469
    1.40
    24.0
    16.0
    WATER BASED
    21.05.1990
    2536
    1.40
    27.0
    15.0
    WATER BASED
    21.05.1990
    2704
    1.40
    26.0
    17.0
    WATER BASED
    21.05.1990
    2704
    1.40
    26.0
    17.0
    WATER BASED
    21.05.1990
    2704
    1.40
    26.0
    17.0
    WATER BASED
    22.05.1990
    2704
    1.40
    26.0
    17.0
    WATER BASED
    21.05.1990
    2756
    1.22
    20.0
    8.0
    WATER BASED
    23.05.1990
    2813
    1.22
    20.0
    8.0
    WATER BASED
    25.05.1990
    2823
    1.22
    20.0
    8.0
    WATER BASED
    25.05.1990
    2825
    1.22
    19.0
    12.0
    WATER BASED
    27.06.1990
    2825
    1.22
    20.0
    12.0
    WATER BASED
    02.07.1990
    2825
    1.22
    17.0
    11.0
    WATER BASED
    02.07.1990
    2825
    1.22
    20.0
    12.0
    WATER BASED
    21.06.1990
    2825
    1.22
    20.0
    11.0
    WATER BASED
    22.06.1990
    2825
    1.22
    20.0
    11.0
    WATER BASED
    25.06.1990
    2825
    1.22
    20.0
    12.0
    WATER BASED
    25.06.1990
    2825
    1.22
    20.0
    12.0
    WATER BASED
    25.06.1990
    2825
    1.22
    19.0
    12.0
    WATER BASED
    26.06.1990
    2825
    1.22
    20.0
    12.0
    WATER BASED
    28.06.1990
    2858
    1.22
    10.0
    11.0
    WATER BASED
    18.06.1990
    2858
    1.22
    19.0
    11.0
    WATER BASED
    18.06.1990
    2858
    1.22
    19.0
    10.0
    WATER BASED
    19.06.1990
    2858
    1.22
    19.0
    11.0
    WATER BASED
    20.06.1990
    2858
    1.22
    19.0
    11.0
    WATER BASED
    13.06.1990
    2858
    1.22
    19.0
    12.0
    WATER BASED
    14.06.1990
    2858
    1.22
    20.0
    13.0
    WATER BASED
    14.06.1990
    2858
    1.22
    17.0
    11.0
    WATER BASED
    18.06.1990
    2869
    1.22
    21.0
    9.0
    WATER BASED
    28.05.1990
    2900
    1.22
    21.0
    9.0
    WATER BASED
    28.05.1990
    3018
    1.23
    23.0
    9.0
    WATER BASED
    28.05.1990
    3098
    1.22
    20.0
    9.0
    WATER BASED
    29.05.1990
    3210
    1.22
    20.0
    9.0
    WATER BASED
    30.05.1990
    3210
    1.22
    19.0
    9.0
    WATER BASED
    31.05.1990
    3210
    1.22
    22.0
    11.0
    WATER BASED
    06.06.1990
    3210
    1.22
    21.0
    12.0
    WATER BASED
    08.06.1990
    3210
    1.22
    21.0
    11.0
    WATER BASED
    11.06.1990
    3210
    1.22
    21.0
    11.0
    WATER BASED
    11.06.1990
    3210
    1.22
    21.0
    11.0
    WATER BASED
    11.06.1990
    3210
    1.22
    21.0
    11.0
    WATER BASED
    12.06.1990
    3210
    1.22
    19.0
    9.0
    WATER BASED
    05.06.1990
    3210
    1.22
    20.0
    8.0
    WATER BASED
    05.06.1990
    3210
    1.22
    23.0
    12.0
    WATER BASED
    05.06.1990
    3210
    1.22
    22.0
    11.0
    WATER BASED
    05.06.1990
    3210
    1.22
    21.0
    11.0
    WATER BASED
    07.06.1990
    3210
    1.22
    19.0
    9.0
    WATER BASED
    05.06.1990
  • 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