Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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34/8-4 A

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  • General information
    General information
    Attribute Value
    Wellbore name
    Official name of wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    34/8-4 A
    Type
    Wellbore type. Legal values: EXPLORATION, DEVELOPMENT, OTHER (see 'Purpose' for more information)
    EXPLORATION
    Purpose
    Final classification of the wellbore.

    Legal values for exploration wellbores:
    WILDCAT, APPRAISAL, WILDCAT-CCS, APPRAISAL-CCS.

    Legal values for development wellbores:
    OBSERVATION, PRODUCTION, INJECTION, INJECTION-CCS, OBSERVATION-CCS.

    Legal values for other wellbores:
    SOIL DRILLING (drilling in connection with track surveys and other subsurface surveys to investigate the soil conditions prior to placement of facilities),
    SHALLOW GAS (drilling to investigate shallow gas before the first 'real' drilling on the location),
    PILOT (drilling to investigate the geology and fluid connectors for location of the main wellbore),
    SCIENTIFIC (drilling according to Law of Scientific research and exploration),
    STRATIGRAPHIC (driling according to Law of Petroleum activities §2-1).
    APPRAISAL
    Status
    Status for the wellbore. Legal values are:

    BLOWOUT: A blowout has occurred in the well.
    CLOSED: A development wellbore that has been closed in a shorter or longer periode. Also applies to development wellbores where drilling is completed, but production/injection has not yet been reported.
    DRILLING: The well is in the drilling phase - can be active drilling, logging, testing or plugging,
    JUNKED: The drilling operation has been terminated due to technical problems.
    P&A: Exploration: The well is plugged and abandoned, and can not be reentered for further use. Development wells: The production/injection from/to the well is stopped and the well is plugged. The wellhead is removed or else made unavailable for further well operations.
    PLUGGED: The wellbore has been plugged, but the upper parts of the wellbore can be re-used. A sidetrack might be drilled at a later stage.
    PRODUCING: It was produced from the wellbore at the time of the operators last monthly report to the Norwegian Offshore Directorate.
    INJECTING: It was injected to the wellbore at the time of the operators last monthly report to the Norwegian Offshore Directorate.
    PREDRILLED: The upper part of the well has been drilled, usually as part of a batch-drilling campaign covering several wellbores.
    RE-CLASS TO DEV: Exploration wellbore that is reclassified to a development wellbore.
    RE-CLASS TO TEST: Exploration wellbore that is reclassified to test production.
    SUSPENDED: The drilling operation in the wellbore has been temporarily stopped. The current plan is to continue drilling later on.
    P&A
    Factmaps in new window
    Main area
    Name of the area on the Norwegian Continental Shelf where the wellbore is located. Legal values: BARENTS SEA, NORWEGIAN SEA, NORTH SEA.
    NORTH SEA
    Field
    Name of the field the wellbore is related to.
    Discovery
    Name of the discovery the wellbore is related to.
    Well name
    Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    34/8-4
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    NH 9001- REKKE 589 & SP. 698
    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.
    711-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.
    100
    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,
    18.02.1992
    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.
    27.05.1992
    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.
    27.05.1994
    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.
    22.04.2005
    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.
    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.
    EARLY 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.
    STATFJORD GP
    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.
    LATE TRIASSIC
    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.
    LUNDE FM
    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.
    309.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3567.0
    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).
    3313.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    33.3
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    123
    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.
    LUNDE FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    61° 19' 29.58'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 25' 18.67'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6799274.11
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    469049.02
    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.
    1909

  • Wellbore history
    General
    Well 34/8-4 A on the Visund Field was initiated as a sidetrack to well 34/8-4 S, which had been temporarily plugged and abandoned. The original well had missed the planned Statfjord Formation target due to structural complexities of the area. The sidetrack should reach the target location, Statfjord Formation, approximately 420 m north-northwest of the surface location in an area of good seismic control. The main objective was to test Statfjord Formation hydrocarbon potential, fluid composition and aquifer characteristics. Secondary objectives were to evaluate the Lunde Formation B/C aquifer characteristics, to establish stratigraphic control of the Base Cretaceous - top Statfjord interval, and to determine the mechanism for hydraulic communication with the Brent reservoir in well 34/8-4S through gravity slide Brent segment and/or through Dunlin Group reservoir.
    Operations and results
    Well 34/8-4 S was re-entered with the semi submersible installation Transocean 8 on 18 February 1992. The sidetrack 34/8-4 A was kicked off from below the 13 3/8" shoe at 2187 m in the primary well bore and drilled to TD at 3567 m in the late Triassic Lunde Formation. No significant problems were encountered during drilling. The well was drilled with a KCl / polymer mud from kick-off to TD.
    A major unconformity was found between the top of the Early Jurassic (Pliensbachian) at 2902.5 m and the overlying Early Cretaceous (Hauterivian). A sandstone member of the Amundsen Formation was encountered from 2942 m to 2989.5 m. One core was taken in this unit and recorded good hydrocarbon shows. Subsequent wire line logs and DST results confirmed that the interval is oil bearing. A gross reservoir thickness of 31.0 m was defined, giving a net pay thickness of 22.38 m. The Statfjord Formation occurred between 3057 m and 3143 m. A total of 7 cores were cut through this interval. Good oil shows were observed throughout.The Lunde Formation was present from 3143 m to TD, at 3567 m and consisted of claystone and distinct interbedded sandstone units. Good shows were recorded in cores in individual sandstone bodies in the upper part of the formation.A total gross reservoir of 205.5 m and a net pay of 115.5 m were defined. An OWC was identified at 3340.5 m.
    Altogether sixteen cores were cut from the Dunlin Group and Statfjord and Lunde Formations with a total of 174 m recovered. RFT samples were taken at 3294.5 m (46 °API oil, gas and water/filtrate) and at 3326.5 m (42 °API oil, gas and water/filtrate). The first oil show was recorded at 2909 m at the top of the Jurassic section and the last at 3342 m in the Lunde Formation.
    The well was suspended on 27 May 1992 as an oil appraisal.
    Testing
    Five DST tests were performed in this well, one in the Lunde Formation, three in the Statfjord Formation, and one in the Dunlin Group. The following flow data are from end of main flow.
    DST 1 in the Lunde Formation perforated the interval 3322.9 m to 3340.9 m and flowed 936 Sm3 oil and 212000 Sm3 gas / day. The GOR was 226 Sm3/Sm3, oil density (@15 °C) was 0.815 g/cm3, and the gas gravity (air = 1) was 0.77 with 1.4 % CO2 and <0.1 ppm H2S.
     DST 2 in the Statfjord Formation perforated the interval 3214.0 m to 3228.0 m and flowed 35 Sm3 oil and 15700 Sm3 gas / day. The GOR was 448 Sm3/Sm3, oil density (@15 °C) was 0.802 g/cm3, and the gas gravity (air = 1) was 0.81 with 1.2 % CO2 and <0.1 ppm H2S.
    DST 3 in the Statfjord Formation perforated the interval 3160.6 m to 3184.6 m and flowed 821 Sm3 oil and 171000 Sm3 gas / day. The GOR was 208 Sm3/Sm3, oil density (@15 °C) was 0.820 g/cm3, and the gas gravity (air = 1) was 0.74 with 1.2 % CO2 and no H2S.
    DST 4 in the Statfjord Formation perforated the interval 3056.0 m to 3108.0 m and flowed 831 Sm3 oil and 181000 Sm3 gas / day. The GOR was 218 Sm3/Sm3, oil density (@15 °C) was 0.821 g/cm3, and the gas gravity (air = 1) was 0.74 with 1.2 % CO2 and 0.5 ppm H2S.
    DST 5 in the Dunlin Group perforated the interval 2988.5 m to 3019.5 m and flowed 992 Sm3 oil and 225000 Sm3 gas / day. The GOR was 227 Sm3/Sm3, oil density (@15 °C) was 0.820 g/cm3, and the gas gravity (air = 1) was 0.74 with 1.2 % CO2 and 0.5 ppm H2S.

  • 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]
    2190.00
    3567.00

  • 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
    2909.0
    2914.1
    [m ]
    2
    2994.0
    3006.1
    [m ]
    3
    3063.0
    3071.8
    [m ]
    4
    3072.5
    3087.7
    [m ]
    5
    3088.0
    3102.6
    [m ]
    6
    3103.0
    3112.4
    [m ]
    7
    3113.5
    3117.7
    [m ]
    8
    3118.5
    3134.7
    [m ]
    9
    3135.0
    3146.3
    [m ]
    10
    3146.5
    3155.0
    [m ]
    11
    3156.0
    3183.0
    [m ]
    12
    3183.0
    3196.2
    [m ]
    13
    3197.5
    3197.8
    [m ]
    14
    3198.5
    3201.0
    [m ]
    15
    3247.5
    3258.4
    [m ]
    16
    3329.0
    3342.5
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    172.8
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 2909-2913m
    Core photo at depth: 2913-2914m
    Core photo at depth: 2994-2998m
    Core photo at depth: 2998-3002m
    Core photo at depth: 3002-3006m
    2909-2913m
    2913-2914m
    2994-2998m
    2998-3002m
    3002-3006m
    Core photo at depth: 3006-3006m
    Core photo at depth: 3063-3067m
    Core photo at depth: 3067-3071m
    Core photo at depth: 3071-3072m
    Core photo at depth: 3072-3076m
    3006-3006m
    3063-3067m
    3067-3071m
    3071-3072m
    3072-3076m
    Core photo at depth: 3076-3080m
    Core photo at depth: 3080-3084m
    Core photo at depth: 3084-3087m
    Core photo at depth: 3088-3092m
    Core photo at depth: 3092-3096m
    3076-3080m
    3080-3084m
    3084-3087m
    3088-3092m
    3092-3096m
    Core photo at depth: 3096-3100m
    Core photo at depth: 3100-3102m
    Core photo at depth: 3103-3107m
    Core photo at depth: 3107-3111m
    Core photo at depth: 3111-3112m
    3096-3100m
    3100-3102m
    3103-3107m
    3107-3111m
    3111-3112m
    Core photo at depth: 3113-3117m
    Core photo at depth: 3118-3123m
    Core photo at depth: 3123-3128m
    Core photo at depth: 3128-3133m
    Core photo at depth: 3133-3134m
    3113-3117m
    3118-3123m
    3123-3128m
    3128-3133m
    3133-3134m
    Core photo at depth: 3135-3140m
    Core photo at depth: 3140-3145m
    Core photo at depth: 3145-3146m
    Core photo at depth: 3146-3151m
    Core photo at depth: 3151-3154m
    3135-3140m
    3140-3145m
    3145-3146m
    3146-3151m
    3151-3154m
    Core photo at depth: 3156-3161m
    Core photo at depth: 3161-3166m
    Core photo at depth: 3166-3171m
    Core photo at depth: 3171-3176m
    Core photo at depth: 3176-3181m
    3156-3161m
    3161-3166m
    3166-3171m
    3171-3176m
    3176-3181m
    Core photo at depth: 3181-3182m
    Core photo at depth: 3183-3188m
    Core photo at depth: 3188-3193m
    Core photo at depth: 3193-3196m
    Core photo at depth: 3197-3198m
    3181-3182m
    3183-3188m
    3188-3193m
    3193-3196m
    3197-3198m
    Core photo at depth: 3198-3201m
    Core photo at depth: 3247-3252m
    Core photo at depth: 3252-3257m
    Core photo at depth: 3257-3258m
    Core photo at depth: 3329-3334m
    3198-3201m
    3247-3252m
    3252-3257m
    3257-3258m
    3329-3334m
    Core photo at depth: 3334-3339m
    Core photo at depth: 3339-3342m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    3334-3339m
    3339-3342m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    2910.1
    [m]
    C
    HYDRO
    2912.5
    [m]
    C
    HYDRO
    2965.0
    [m]
    SWC
    HYDRO
    2985.0
    [m]
    SWC
    HYDRO
    3000.3
    [m]
    C
    HYDRO
    3003.8
    [m]
    C
    HYDRO
    3020.0
    [m]
    SWC
    HYDRO
    3050.0
    [m]
    SWC
    HYDRO
    3055.0
    [m]
    SWC
    HYDRO
    3069.0
    [m]
    C
    HYDRO
    3074.0
    [m]
    C
    HYDRO
    3094.1
    [m]
    C
    HYDRO
    3110.2
    [m]
    C
    HYDRO
    3116.6
    [m]
    C
    HYDRO
    3117.4
    [m]
    C
    HYDRO
    3119.5
    [m]
    C
    HYDRO
    3125.3
    [m]
    C
    HYDRO
    3149.9
    [m]
    C
    HYDRO
    3150.3
    [m]
    C
    HYDRO
    3159.5
    [m]
    C
    HYDRO
    3181.3
    [m]
    C
    HYDRO
    3186.6
    [m]
    C
    HYDRO
    3194.7
    [m]
    C
    HYDRO
    3220.0
    [m]
    SWC
    HYDRO
    3225.0
    [m]
    SWC
    HYDRO
    3230.0
    [m]
    SWC
    HYDRO
    3235.0
    [m]
    SWC
    HYDRO
    3250.8
    [m]
    SWC
    HYDRO
    3275.0
    [m]
    SWC
    HYDRO
    3330.6
    [m]
    C
    HYDRO
    3340.6
    [m]
    C
    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
    DST1
    3322.90
    3340.90
    OIL
    09.04.1992 - 17:30
    YES
    DST
    DST2
    0.00
    0.00
    OIL
    22.04.1992 - 00:00
    YES
    DST
    DST4
    0.00
    0.00
    OIL
    12.05.1992 - 22:15
    YES

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.56

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    5.30

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    3323
    3341
    14.2
    2.0
    3214
    3228
    12.7
    3.0
    3160
    3184
    19.0
    4.0
    3056
    3108
    12.7
    5.0
    2988
    3019
    14.3
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    23.000
    49.000
    118
    2.0
    1.000
    7.000
    105
    3.0
    11.000
    27.000
    113
    4.0
    26.000
    45.000
    110
    5.0
    26.000
    44.000
    109
    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
    936
    211536
    0.815
    0.770
    226
    2.0
    35
    15680
    0.800
    0.810
    448
    3.0
    821
    170768
    0.820
    0.740
    208
    4.0
    831
    181158
    0.821
    0.740
    218
    5.0
    992
    225184
    0.820
    0.740
    227

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    ASI GR
    2235
    3485
    CST GR
    2300
    3522
    DIL LSS LDL CNL NGT SP
    1838
    3564
    DLL MSFL LDL CNL GR AMS
    2960
    3156
    DLL MSFL LSS GR AMS
    2140
    3393
    MDT GR AMS
    2991
    3413
    MDT GR AMS
    3294
    3448
    MWD - GR RES DIR
    2187
    3504
    SHDT GR AMS
    2850
    3537

  • 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
    417.0
    36
    420.0
    0.00
    LOT
    INTERM.
    18 5/8
    1146.0
    26
    1150.0
    1.58
    LOT
    INTERM.
    13 3/8
    2161.0
    17 1/2
    2165.0
    1.78
    LOT
    INTERM.
    9 5/8
    3567.0
    12 1/4
    3567.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    550
    1.71
    22.0
    WATER BASED
    2188
    1.64
    30.0
    WATER BASED
    2230
    1.70
    27.0
    WATER BASED
    2250
    1.64
    31.0
    WATER BASED
    2434
    1.64
    30.0
    WATER BASED
    2509
    1.63
    35.0
    WATER BASED
    2615
    1.64
    34.0
    WATER BASED
    2700
    1.70
    20.0
    WATER BASED
    2813
    1.64
    37.0
    WATER BASED
    2909
    1.64
    36.0
    WATER BASED
    2914
    1.64
    40.0
    WATER BASED
    2994
    1.64
    40.0
    WATER BASED
    3012
    1.70
    33.0
    WATER BASED
    3037
    1.70
    20.0
    WATER BASED
    3042
    1.65
    37.0
    WATER BASED
    3073
    1.66
    40.0
    WATER BASED
    3103
    1.66
    41.0
    WATER BASED
    3114
    1.66
    41.0
    WATER BASED
    3120
    1.66
    39.0
    WATER BASED
    3144
    1.70
    30.0
    WATER BASED
    3147
    1.66
    40.0
    WATER BASED
    3150
    1.70
    32.0
    WATER BASED
    3156
    1.66
    37.0
    WATER BASED
    3156
    1.66
    37.0
    WATER BASED
    3183
    1.65
    37.0
    WATER BASED
    3197
    1.70
    32.0
    WATER BASED
    3198
    1.65
    39.0
    WATER BASED
    3200
    1.65
    39.0
    WATER BASED
    3202
    1.65
    39.0
    WATER BASED
    3248
    1.70
    32.0
    WATER BASED
    3259
    1.65
    35.0
    WATER BASED
    3272
    1.65
    35.0
    WATER BASED
    3342
    1.65
    39.0
    WATER BASED
    3447
    1.65
    33.0
    WATER BASED
    3500
    1.71
    35.0
    WATER BASED
    3504
    1.65
    37.0
    WATER BASED
    3567
    1.64
    38.0
    WATER BASED

  • 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