Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
24.11.2024 - 01:27
Time of last synchronization with Norwegian Offshore Directorate's internal systems

6608/10-4

Export: PDF icon PDF

  • General information
    General information
    Attribute Value
    Wellbore name
    Official name of wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    6608/10-4
    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.
    NORWEGIAN SEA
    Field
    Name of the field the wellbore is related to.
    Discovery
    Name of the discovery the wellbore is related to.
    Well name
    Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    6608/10-4
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    ST 9203-CROSSLINE 2051& INLINE 1230
    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.
    Den norske stats oljeselskap a.s
    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.
    776-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.
    82
    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,
    15.12.1993
    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.
    06.03.1994
    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.
    06.03.1996
    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.
    24.09.2002
    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/GAS
    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.
    YES
    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.
    INTRA MELKE FM SS
    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.
    MIDDLE JURASSIC
    2nd level with HC, formation
    Name of lithostartigraphic unit, 2nd level, where hydrocarbons were encountered. Shown only for released wells. Examples of legal values: BASEMENT, COOK FM, EKOFISK FM, HEIMDAL FM, SANDNES FM, SOGNEFJORD FM, TARBERT FM, BRENT GP.
    GARN FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    23.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    382.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2800.0
    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).
    2800.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    3.3
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    103
    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.
    ÅRE FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    66° 2' 25.26'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    8° 9' 41.74'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7324847.23
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    462006.74
    UTM zone
    Universal Transverse Mercator zone. Examples of legal values: 31, 32, 33, 34.
    32
    NPDID wellbore
    Norwegian Offshore Directorate's unique id for the wellbore.
    2256

  • Wellbore history
    General
    The main objective of well 6608/10-4 was to prove oil accumulation in the Middle Jurassic Sandstones in the Norne Northeast segment.
    Operations and results
    Wildcat well 6608/10-4 was spudded on 15 December 1993 with the semi-submersible installation "Ross Isle" and drilled to a total depth of 2800 m, in rocks of the Lower Jurassic Åre Formation. The well was drilled entirely water based with sea water and hi-vis pills to 818 m, and Gyp/PAC mud from 818 m to TD. Oil was encountered in the Middle Jurassic in the Melke Formation Sandstones and in the Garn Formation. One core was cut in the Cretaceous Nise Formation from 2091.0 m to 2095.5 m. Seven cores were cut in the interval from 2560.0 m in the Melke Formation to 2709 m in the Åre Formation. Core recovery varied between 92% and 100%. Segregated FMT samples were taken in the Melke, Garn, and Ile Formations. The Melke samples contained mainly mud filtrate with small amounts/traces of oil and gas, the Garn samples failed due to lost seal, while the Ile samples recovered only mud filtrate. The well was plugged and abandoned on 7 March 1994 as an oil and gas discovery.
    Testing
    Three drill stem tests were performed in the well. One test, DST 1, tested the Tofte Formation in the interval 2635 to 2640 m. The second test, DST 2, tested the Garn Formation in the interval 2566.2 to 2582.2 m. The Melke Formation was tested in two steps: DST 3A in the intervals 2484.5 - 2499 and 2504 - 2514 m, and DST 3B in the interval 2524 to 2531 in addition to intervals 3A. During DST 1 and DST 3A and 3B no formation fluid were produced to the surface. DST 3 proved that the Melke Formation was tight with oil in place. DST 2 produced a maximum of 900 Sm3/D of oil with a density of 858 kg/m3 at standard conditions and 75000 Sm3/D of gas with a relative density of 0.648 (air = 1.0) through an 80/64" (31.75 mm) choke. Minifrac tests were performed at the end of DST 1 and DST 2. The fracture closing pressures are evaluated to be: DST 1 405 bar and DST 2 410 bar.

  • 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]
    820.00
    2800.00

  • 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
    2
    2560.0
    2586.2
    [m ]
    3
    2587.0
    2615.2
    [m ]
    4
    2615.2
    2641.9
    [m ]
    5
    2642.0
    2660.0
    [m ]
    6
    2660.0
    2673.0
    [m ]
    7
    2673.0
    2682.5
    [m ]
    8
    2683.0
    2707.1
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    145.6
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 0-0m
    Core photo at depth: 2560-2565m
    Core photo at depth: 2565-2570m
    Core photo at depth: 2570-2575m
    Core photo at depth: 2575-2580m
    0-0m
    2560-2565m
    2565-2570m
    2570-2575m
    2575-2580m
    Core photo at depth: 2580-2585m
    Core photo at depth: 2585-2586m
    Core photo at depth: 2587-2592m
    Core photo at depth: 2592-2597m
    Core photo at depth: 2597-2602m
    2580-2585m
    2585-2586m
    2587-2592m
    2592-2597m
    2597-2602m
    Core photo at depth: 2602-2607m
    Core photo at depth: 2607-2612m
    Core photo at depth: 2612-2615m
    Core photo at depth: 2615-2620m
    Core photo at depth: 2620-2625m
    2602-2607m
    2607-2612m
    2612-2615m
    2615-2620m
    2620-2625m
    Core photo at depth: 2625-2630m
    Core photo at depth: 2630-2635m
    Core photo at depth: 2635-2640m
    Core photo at depth: 2640-2642m
    Core photo at depth: 2642-2647m
    2625-2630m
    2630-2635m
    2635-2640m
    2640-2642m
    2642-2647m
    Core photo at depth: 2647-2652m
    Core photo at depth: 2652-2657m
    Core photo at depth: 2657-2660m
    Core photo at depth: 2660-2665m
    Core photo at depth: 2665-2670m
    2647-2652m
    2652-2657m
    2657-2660m
    2660-2665m
    2665-2670m
    Core photo at depth: 2670-2673m
    Core photo at depth: 2673-2678m
    Core photo at depth: 2678-2682m
    Core photo at depth: 2683-2688m
    Core photo at depth: 2688-2693m
    2670-2673m
    2673-2678m
    2678-2682m
    2683-2688m
    2688-2693m
    Core photo at depth: 2693-2698m
    Core photo at depth: 2698-2703m
    Core photo at depth: 2703-2707m
    Core photo at depth:  
    Core photo at depth:  
    2693-2698m
    2698-2703m
    2703-2707m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1922.0
    [m]
    SWC
    STATO
    1940.0
    [m]
    DC
    GEOST
    1960.0
    [m]
    DC
    GEOST
    1972.0
    [m]
    SWC
    STATO
    1980.0
    [m]
    SWC
    STATO
    1999.0
    [m]
    DC
    GEOST
    2011.0
    [m]
    DC
    GEOST
    2025.0
    [m]
    SWC
    STATO
    2045.0
    [m]
    SWC
    STATO
    2062.0
    [m]
    DC
    GEOST
    2077.0
    [m]
    DC
    GEOST
    2110.0
    [m]
    DC
    GEOST
    2125.0
    [m]
    DC
    GEOST
    2140.0
    [m]
    DC
    GEOST
    2155.0
    [m]
    DC
    GEOST
    2170.0
    [m]
    DC
    GEOST
    2175.0
    [m]
    SWC
    STATO
    2190.0
    [m]
    SWC
    STATO
    2206.0
    [m]
    DC
    GEOST
    2222.0
    [m]
    SWC
    STATO
    2239.0
    [m]
    DC
    GEOST
    2251.0
    [m]
    DC
    GEOST
    2267.0
    [m]
    SWC
    STATO
    2281.0
    [m]
    DC
    GEOST
    2300.0
    [m]
    SWC
    STATO
    2315.0
    [m]
    SWC
    STATO
    2320.0
    [m]
    SWC
    STATO
    2325.0
    [m]
    SWC
    STATO
    2335.0
    [m]
    SWC
    STATO
    2347.0
    [m]
    DC
    GEOST
    2355.0
    [m]
    SWC
    STATO
    2360.0
    [m]
    SWC
    STATO
    2371.0
    [m]
    DC
    GEOST
    2380.0
    [m]
    DC
    GEOST
    2395.0
    [m]
    DC
    GEOST
    2407.0
    [m]
    DC
    GEOST
    2416.0
    [m]
    DC
    GEOST
    2431.0
    [m]
    DC
    GEOST
    2443.0
    [m]
    DC
    GEOST
    2455.0
    [m]
    DC
    GEOST
    2464.0
    [m]
    DC
    GEOST
    2473.0
    [m]
    DC
    GEOST
    2480.0
    [m]
    SWC
    STATO
    2490.0
    [m]
    SWC
    STATO
    2495.0
    [m]
    SWC
    STATO
    2500.0
    [m]
    SWC
    STATO
    2507.0
    [m]
    SWC
    STATO
    2520.0
    [m]
    SWC
    STATO
    2525.0
    [m]
    SWC
    STATO
    2530.0
    [m]
    DC
    GEOST
    2535.0
    [m]
    SWC
    STATO
    2542.0
    [m]
    DC
    GEOST
    2545.0
    [m]
    DC
    GEOST
    2548.0
    [m]
    DC
    GEOST
    2554.0
    [m]
    DC
    GEOST
    2557.0
    [m]
    DC
    GEOST
    2560.3
    [m]
    C
    STATO
    2563.8
    [m]
    C
    STATO
    2565.9
    [m]
    C
    STATO
    2569.0
    [m]
    C
    STATO
    2571.3
    [m]
    C
    STATO
    2573.7
    [m]
    C
    STATO
    2576.5
    [m]
    C
    STATO
    2580.5
    [m]
    C
    STATO
    2586.2
    [m]
    C
    STATO
    2590.9
    [m]
    C
    STATO
    2592.4
    [m]
    C
    STATO
    2596.8
    [m]
    C
    STATO
    2599.8
    [m]
    C
    STATO
    2603.8
    [m]
    C
    STATO
    2604.7
    [m]
    C
    STATO
    2605.7
    [m]
    C
    STATO
    2608.3
    [m]
    C
    STATO
    2609.3
    [m]
    C
    STATO
    2609.7
    [m]
    C
    STATO
    2611.7
    [m]
    C
    STATO
    2612.4
    [m]
    C
    STATO
    2614.5
    [m]
    C
    STATO
    2614.7
    [m]
    C
    STATO
    2615.2
    [m]
    C
    STATO
    2615.4
    [m]
    C
    STATO
    2618.6
    [m]
    C
    STATO
    2622.0
    [m]
    C
    STATO
    2627.5
    [m]
    C
    STATO
    2631.6
    [m]
    C
    STATO
    2635.6
    [m]
    C
    STATO
    2640.8
    [m]
    C
    STATO
    2643.3
    [m]
    C
    STATO
    2647.3
    [m]
    C
    STATO
    2651.3
    [m]
    C
    STATO
    2653.6
    [m]
    C
    STATO
    2660.6
    [m]
    C
    STATO
    2667.6
    [m]
    C
    STATO
    2670.8
    [m]
    C
    STATO
    2671.2
    [m]
    C
    STATO
    2672.0
    [m]
    C
    STATO
    2672.4
    [m]
    C
    STATO
    2673.9
    [m]
    C
    STATO
    2680.9
    [m]
    C
    STATO
    2687.4
    [m]
    C
    STATO
    2692.7
    [m]
    C
    STATO
    2696.4
    [m]
    C
    STATO
    2702.7
    [m]
    C
    STATO
    2706.8
    [m]
    C
    STATO
    2715.0
    [m]
    SWC
    STATO
    2719.0
    [m]
    DC
    GEOST
    2722.0
    [m]
    DC
    GEOST
    2726.0
    [m]
    SWC
    STATO
    2731.0
    [m]
    DC
    GEOST
    2737.0
    [m]
    DC
    GEOST
    2739.2
    [m]
    SWC
    STATO
    2743.0
    [m]
    DC
    GEOST
    2746.0
    [m]
    DC
    GEOST
    2750.0
    [m]
    SWC
    STATO
    2758.0
    [m]
    DC
    GEOST
    2762.0
    [m]
    SWC
    STATO
    2764.0
    [m]
    DC
    GEOST
    2770.0
    [m]
    DC
    GEOST
    2774.0
    [m]
    SWC
    STATO

  • 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
    DST2
    2582.20
    2466.20
    OIL
    16.02.1994 - 00:20
    YES
    DST
    DST3AB
    2514.00
    2484.50
    23.02.1994 - 20:00
    YES

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.27

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    1.94
    pdf
    1.98
    pdf
    1.78

  • 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
    44.34

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    2640
    2635
    0.0
    2.0
    2582
    2466
    31.7
    3.1
    2485
    2514
    0.0
    3.2
    2524
    2531
    0.0
    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
    40.000
    94
    3.1
    3.2
    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
    2.0
    900
    75000
    0.858
    0.648
    83
    3.1
    3.2

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL VDL GR
    800
    2746
    DIFL MAC SL
    2175
    2795
    DLL MLL GR
    2465
    2650
    FMT GR
    2485
    2662
    HRDIP GR
    1396
    2555
    MWD
    477
    2558
    SWC GR
    1430
    2774
    VSP
    500
    2750
    ZDL CNL GR
    2465
    2794

  • 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
    464.0
    36
    465.0
    0.00
    LOT
    SURF.COND.
    20
    794.0
    26
    796.0
    1.50
    LOT
    INTERM.
    13 3/8
    1401.0
    17 1/2
    1402.0
    1.83
    LOT
    INTERM.
    9 5/8
    2540.0
    12 1/4
    2542.0
    1.83
    LOT
    LINER
    7
    2800.0
    8 1/2
    2800.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    415
    1.03
    20.0
    DUMMY
    452
    1.12
    WATER BASED
    735
    1.20
    DUMMY
    896
    1.14
    25.0
    WATER BASED
    1415
    1.25
    23.0
    WATER BASED
    1777
    1.57
    33.0
    WATER BASED
    1920
    1.60
    31.0
    WATER BASED
    2063
    1.57
    38.0
    WATER BASED
    2090
    1.57
    30.0
    WATER BASED
    2103
    1.60
    37.0
    WATER BASED
    2265
    1.60
    28.0
    WATER BASED
    2329
    1.60
    29.0
    WATER BASED
    2431
    1.60
    27.0
    WATER BASED
    2486
    1.60
    35.0
    WATER BASED
    2540
    1.25
    25.0
    WATER BASED
    2558
    1.60
    32.0
    WATER BASED
    2560
    1.20
    17.0
    WATER BASED
    2587
    1.20
    23.0
    WATER BASED
    2614
    1.20
    22.0
    WATER BASED
    2640
    1.20
    22.0
    WATER BASED
    2660
    1.20
    22.0
    WATER BASED
    2683
    1.20
    23.0
    WATER BASED
    2709
    1.20
    23.0
    WATER BASED
    2800
    1.20
    21.0
    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
    0.28