Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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19.07.2024 - 01:27
Time of last synchronization with Norwegian Offshore Directorate's internal systems

7/7-2

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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.
    7/7-2
    Type
    Wellbore type. Legal values: EXPLORATION, DEVELOPMENT, OTHER (see 'Purpose' for more information)
    EXPLORATION
    Purpose
    Final classification of the wellbore.

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

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

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

    BLOWOUT: A blowout has occurred in the well.
    CLOSED: A development wellbore that has been closed in a shorter or longer periode. Also applies to development wellbores where drilling is completed, but production/injection has not yet been reported.
    DRILLING: The well is in the drilling phase - can be active drilling, logging, testing or plugging,
    JUNKED: The drilling operation has been terminated due to technical problems.
    P&A: Exploration: The well is plugged and abandoned, and can not be reentered for further use. Development wells: The production/injection from/to the well is stopped and the well is plugged. The wellhead is removed or else made unavailable for further well operations.
    PLUGGED: The wellbore has been plugged, but the upper parts of the wellbore can be re-used. A sidetrack might be drilled at a later stage.
    PRODUCING: It was produced from the wellbore at the time of the operators last monthly report to the Norwegian Offshore Directorate.
    INJECTING: It was injected to the wellbore at the time of the operators last monthly report to the Norwegian Offshore Directorate.
    PREDRILLED: The upper part of the well has been drilled, usually as part of a batch-drilling campaign covering several wellbores.
    RE-CLASS TO DEV: Exploration wellbore that is reclassified to a development wellbore.
    RE-CLASS TO TEST: Exploration wellbore that is reclassified to test production.
    SUSPENDED: The drilling operation in the wellbore has been temporarily stopped. The current plan is to continue drilling later on.
    P&A
    Factmaps in new window
    Main area
    Name of the area on the Norwegian Continental Shelf where the wellbore is located. Legal values: BARENTS SEA, NORWEGIAN SEA, NORTH SEA.
    NORTH SEA
    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.
    7/7-2
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    AHN 8707 - 212 SP. 110
    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.
    710-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.
    97
    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,
    20.01.1992
    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.
    25.04.1992
    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.
    25.04.1994
    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.
    19.10.2006
    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
    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.
    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.
    23.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    82.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3430.0
    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).
    3430.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    3.4
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    147
    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 PERMIAN
    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.
    ZECHSTEIN GP
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    57° 29' 4.16'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 18' 17.59'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6371675.99
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    458321.93
    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.
    1868
  • Wellbore history

    General
    Well 7/7-2 is located ca 8 km east of the UK border on the Jæren High in the North Sea. It was the second commitment well within the licence PL-148 and was designed to test the A-prospect, interpreted as a Late Jurassic channel sandstone. Planned TD was in Permian sediments or 3500 m, whichever came first.
    Operations and results
    Wildcat well 7/7-2 was spudded with the semi-submersible installation Deepsea Bergen on 20 January 1992 and drilled to TD at 3430 m in the Permian Zechstein Group. The well took 100 days to drill and test, 20 days more than planned. This was mainly due to a 25% higher pore pressure than prognosed in the reservoir, resulting in a plug-back and 9 5/8" casing above reservoir, and not at TD as programmed. Other contributing factors were re-spud after lost stinger in 30" casing, two occasions of pulling BOP due to leakage and leak on swivel stem on top drive. The DSTs experienced severe difficulties with leakage and operation of down hole valves resulting in two mis-runs with testing string and a shortened DST no. 2. The well was drilled with CMC EHV and seawater down to 904 m, with KCl/PHPA/PAC from 904 m to 2744 m, and with ANCOTEMP mud from 2744 m to TD.
    The greater part of the prospect, the Late Jurassic Ula sandstone was encountered at 3327 m, and proved to be sandy. The Jurassic reservoir lithology consisted primarily of fine, well-sorted silica-cemented sandstone with poor visual porosity. Subsequent testing from 3348 - 3350 m showed a very tight formation, however testing from 3333 - 3342 m yielded oil. No oil-water contact was encountered, but organic geochemical analyses detected oil saturation in two intervals from the top of the reservoirs down to 3341, and from 3345 down to 3347 m.
    Four and a half m of shaley core was recovered in two cores from 3242 m to 3247 in the Mandal Formation. Good oil shows were observed in these cores. Organic geochemical analyses proved them to be excellent oil-prone source rock and with a maturity well within the oil window. Three cores were cut from 3338 m to 3363 m in the lower part of the Ula Formation and 17 m into the Triassic Smith Bank Formation. FMT pressures indicated a 0.766 g/cm3 oil gradient over the reservoir interval. Two FMT fluid samples were taken. Sample 4B at 3334 m recovered only mud filtrate. Sample 4C at 3335.4 m recovered 18.6 l mud filtrate and 200 ml of HC film.
    The well was permanently abandoned on 25 April 1992 as an oil discovery.
    Testing
    Two drill stem tests were performed in the well, DST 1 in Triassic sandstones and DST 2 in sandstones of Late Jurassic age. In DST 1 a two-metre interval from 3348 m to 3350 m was perforated. No reservoir fluid was produced to surface, but oil was trapped between two valves in the test string and the string content was also reversed out and directed to tank. Approximately 15 litres of oil were recovered from the test.
    The well was perforated from 3333 m to 3342 m in DST 2. It produced 784 Sm3/d of oil through a 24/64" (9.53 mm) choke, with a wellhead pressure of 15218 kPa and a temperature of 80 °C. The gas-oil ratio was measured to 20 Sm3/Sm3 with a separator pressure of 2032 - 2150 kPa and a separator temperature of 65 - 71 °C. Maximum down hole temperature was 144 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]
    910.00
    3422.00
  • 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
    3242.0
    3243.0
    [m ]
    2
    3243.0
    3246.5
    [m ]
    3
    3338.0
    3348.6
    [m ]
    4
    3350.0
    3357.1
    [m ]
    5
    3357.0
    3368.4
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    33.6
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES
  • Core photos

    Core photos
    Core photo at depth: 3242-3243m
    Core photo at depth: 3243-3246m
    Core photo at depth: 3338-3343m
    Core photo at depth: 3348-3349m
    Core photo at depth: 3350-3355m
    3242-3243m
    3243-3246m
    3338-3343m
    3348-3349m
    3350-3355m
    Core photo at depth: 3355-3357m
    Core photo at depth: 3357-3362m
    Core photo at depth: 3362-3363m
    Core photo at depth:  
    Core photo at depth:  
    3355-3357m
    3357-3362m
    3362-3363m
  • Palynological slides at the Norwegian Offshore Directorate

    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1350.0
    [m]
    DC
    MILL
    1370.0
    [m]
    DC
    MILL
    1380.0
    [m]
    DC
    MILL
    1390.0
    [m]
    DC
    MILL
    1400.0
    [m]
    DC
    MILL
    1430.0
    [m]
    DC
    MILL
    1440.0
    [m]
    DC
    MILL
    1460.0
    [m]
    DC
    MILL
    1470.0
    [m]
    DC
    MILL
    1490.0
    [m]
    DC
    MILL
    1500.0
    [m]
    DC
    MILL
    1520.0
    [m]
    DC
    MILL
    1530.0
    [m]
    DC
    MILL
    1550.0
    [m]
    DC
    MILL
    1560.0
    [m]
    DC
    MILL
    1580.0
    [m]
    DC
    MILL
    1590.0
    [m]
    DC
    MILL
    1610.0
    [m]
    DC
    MILL
    1620.0
    [m]
    DC
    MILL
    1640.0
    [m]
    DC
    MILL
    1650.0
    [m]
    DC
    MILL
    1670.0
    [m]
    DC
    MILL
    1680.0
    [m]
    DC
    MILL
    1690.0
    [m]
    DC
    MILL
    1710.0
    [m]
    DC
    MILL
    1730.0
    [m]
    DC
    MILL
    1740.0
    [m]
    DC
    MILL
    1760.0
    [m]
    DC
    MILL
    1770.0
    [m]
    DC
    MILL
    1790.0
    [m]
    DC
    MILL
    1800.0
    [m]
    DC
    MILL
    1820.0
    [m]
    DC
    MILL
    1830.0
    [m]
    DC
    MILL
    1850.0
    [m]
    DC
    MILL
    1860.0
    [m]
    DC
    MILL
    1880.0
    [m]
    DC
    MILL
    1890.0
    [m]
    DC
    MILL
    1910.0
    [m]
    DC
    MILL
    1920.0
    [m]
    DC
    MILL
    1940.0
    [m]
    DC
    MILL
    1950.0
    [m]
    DC
    MILL
    1970.0
    [m]
    DC
    MILL
    1980.0
    [m]
    DC
    MILL
    2000.0
    [m]
    DC
    MILL
    2010.0
    [m]
    DC
    MILL
    2030.0
    [m]
    DC
    MILL
    2040.0
    [m]
    DC
    MILL
    2060.0
    [m]
    DC
    MILL
    2070.0
    [m]
    DC
    MILL
    2090.0
    [m]
    DC
    MILL
    2100.0
    [m]
    DC
    MILL
    2120.0
    [m]
    DC
    MILL
    2130.0
    [m]
    DC
    MILL
    2150.0
    [m]
    DC
    MILL
    2160.0
    [m]
    DC
    MILL
    2180.0
    [m]
    DC
    MILL
    2190.0
    [m]
    DC
    MILL
    2210.0
    [m]
    DC
    MILL
    2220.0
    [m]
    DC
    MILL
    2240.0
    [m]
    DC
    MILL
    2250.0
    [m]
    DC
    MILL
    2270.0
    [m]
    DC
    MILL
    2280.0
    [m]
    DC
    MILL
    2300.0
    [m]
    DC
    MILL
    2310.0
    [m]
    DC
    MILL
    2330.0
    [m]
    DC
    MILL
    2340.0
    [m]
    DC
    MILL
    2360.0
    [m]
    DC
    MILL
    2370.0
    [m]
    DC
    MILL
    2390.0
    [m]
    DC
    MILL
    2400.0
    [m]
    DC
    MILL
    2415.0
    [m]
    DC
    MILL
    2430.0
    [m]
    DC
    MILL
    2448.0
    [m]
    DC
    MILL
    2460.0
    [m]
    DC
    MILL
    2475.0
    [m]
    DC
    MILL
    2490.0
    [m]
    DC
    MILL
    2505.0
    [m]
    DC
    MILL
    2520.0
    [m]
    DC
    MILL
    2535.0
    [m]
    DC
    MILL
    2550.0
    [m]
    DC
    MILL
    2565.0
    [m]
    DC
    MILL
    2580.0
    [m]
    DC
    MILL
    2595.0
    [m]
    DC
    MILL
    2610.0
    [m]
    DC
    MILL
    2625.0
    [m]
    DC
    MILL
    2640.0
    [m]
    DC
    MILL
    2655.0
    [m]
    DC
    MILL
    2670.0
    [m]
    DC
    MILL
    2685.0
    [m]
    DC
    MILL
    2700.0
    [m]
    DC
    MILL
    2715.0
    [m]
    DC
    MILL
    3100.0
    [m]
    DC
    MILL
    3110.0
    [m]
    DC
    MILL
    3120.0
    [m]
    DC
    MILL
    3140.0
    [m]
    DC
    MILL
    3170.0
    [m]
    DC
    MILL
    3180.0
    [m]
    DC
    MILL
    3200.0
    [m]
    DC
    MILL
    3215.0
    [m]
    DC
    MILL
    3219.0
    [m]
    SWC
    STATO
    3230.0
    [m]
    DC
    MILL
    3241.0
    [m]
    SWC
    STATO
    3251.0
    [m]
    DC
    MILL
    3258.0
    [m]
    SWC
    STATO
    3263.0
    [m]
    SWC
    STATO
    3266.0
    [m]
    SWC
    STATO
    3271.0
    [m]
    SWC
    STATO
    3275.0
    [m]
    DC
    MILL
    3278.0
    [m]
    DC
    MILL
    3284.0
    [m]
    DC
    MILL
    3290.0
    [m]
    DC
    MILL
    3296.0
    [m]
    DC
    MILL
    3302.0
    [m]
    DC
    MILL
    3308.0
    [m]
    DC
    MILL
    3314.0
    [m]
    DC
    MILL
    3320.0
    [m]
    DC
    MILL
    3326.0
    [m]
    DC
    MILL
    3332.0
    [m]
    SWC
    STATO
    3338.3
    [m]
    C
    STATO
    3339.3
    [m]
    C
    STATO
    3339.7
    [m]
    C
    STATO
    3339.9
    [m]
    C
    STATO
    3340.1
    [m]
    C
    STATO
    3341.8
    [m]
    C
    STATO
    3342.4
    [m]
    C
    STATO
    3343.2
    [m]
    C
    STATO
    3344.1
    [m]
    C
    STATO
    3346.5
    [m]
    C
    STATO
    3348.6
    [m]
    C
    MILL
    3358.7
    [m]
    C
    STATO
    3377.0
    [m]
    DC
    MILL
    3386.0
    [m]
    DC
    MILL
    3395.0
    [m]
    DC
    MILL
    3404.0
    [m]
    DC
    MILL
    3413.0
    [m]
    DC
    MILL
    3422.0
    [m]
    DC
    MILL
    3428.0
    [m]
    DC
    MILL
  • 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
    TEST2
    3333.00
    3342.00
    15.04.1992 - 00:00
    YES
  • Lithostratigraphy

  • Composite logs

    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.60
  • Geochemical information

    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    2.85
  • 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
    20.42
  • Drill stem tests (DST)

    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    3333
    3342
    9.5
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    35.000
    15.000
    80
    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
    787
    15740
    0.877
    0.840
    20
  • Logs

    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL VDL GR
    1000
    2727
    CBL VDL GR
    1500
    3283
    CDL CN SPL
    3285
    3431
    CDL CN SPL GR
    2727
    3304
    DIFL ACL GR
    2727
    3303
    DIFL ACL MLL GR
    3285
    3431
    DIFL ACL ZDL GR
    886
    2734
    DIPLOG
    3285
    3432
    DIPS GR
    3075
    3304
    FMT GR
    3316
    3333
    FMT HP SG GR
    3334
    3374
    FMT SG GR
    3335
    0
    MWD - GR RES DIR
    105
    3430
    SWC
    3328
    3410
    SWC GR
    3110
    3282
    VELOCITY
    1515
    3425
    VSP
    470
    3420
  • 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
    165.0
    36
    165.0
    0.00
    LOT
    INTERM.
    20
    886.0
    26
    886.0
    2.05
    LOT
    INTERM.
    13 3/8
    2728.0
    17 1/2
    2728.0
    2.00
    LOT
    INTERM.
    9 5/8
    3283.0
    12 1/4
    3283.0
    2.05
    LOT
    LINER
    7
    3420.0
    8 1/2
    3420.0
    0.00
    LOT
  • Drilling mud

    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    1920
    1.55
    34.0
    WATER BASED
    2077
    1.55
    39.0
    WATER BASED
    2083
    1.55
    34.0
    WATER BASED
    2182
    1.55
    30.0
    WATER BASED
    2330
    1.60
    24.0
    WATER BASED
    2448
    1.55
    34.0
    WATER BASED
    2525
    1.55
    32.0
    WATER BASED
    2586
    1.55
    36.0
    WATER BASED
    2719
    1.55
    32.0
    WATER BASED
    2744
    1.60
    24.0
    WATER BASED
    2840
    1.55
    30.0
    WATER BASED
    2949
    1.55
    36.0
    WATER BASED
    3043
    1.60
    41.0
    WATER BASED
    3100
    1.62
    40.0
    WATER BASED
    3117
    1.67
    40.0
    WATER BASED
    3121
    1.62
    43.0
    WATER BASED
    3166
    1.62
    40.0
    WATER BASED
    3242
    1.67
    38.0
    WATER BASED
    3293
    1.70
    48.0
    WATER BASED
    3312
    1.70
    43.0
    WATER BASED
    3328
    1.87
    26.0
    WATER BASED
    3330
    1.95
    39.0
    WATER BASED
    3334
    2.04
    26.0
    WATER BASED
    3338
    1.96
    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
    0.22