Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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14.07.2024 - 01:28
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6609/11-1

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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.
    6609/11-1
    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
    Well name
    Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    6609/11-1
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    NH 8102 - 415 SP 4335
    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.
    374-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.
    50
    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,
    19.05.1983
    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.
    07.07.1983
    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.
    07.07.1985
    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.
    15.06.2005
    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.
    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.
    DRY
    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
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    25.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    238.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3068.0
    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).
    3067.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    5.8
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    90
    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.
    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° 8' 13.9'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    9° 33' 47.89'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7335502.71
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    525429.99
    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.
    15
  • Wellbore history

    General
    Wildcat well 6609/11-1 was drilled on the Northwestern side of the Helgeland Basin outside Mid Norway. The primary objective was to test sandstone reservoirs of Middle to Early Jurassic age in a structurally high position on a narrow SW-NE trending horst block. The secondary objective was to test sandstone reservoirs of Early Jurassic to Upper Triassic age. The well was planned to be drilled to 3200 m, 200 m into the Triassic.
    Operations and results
    Wildcat well 6609/11-1 was spudded with the semi-submersible installation Treasure Seeker on 19 May 1983 and drilled to TD at 3068 m in Late Triassic sediments of the Åre Formation. No major technical problems occurred during drilling. Operations were interrupted for 11 and a half days due to a crew strike. The well was drilled with seawater and hi-vis pills to 915 m and with gypsum/polymer mud from 915 m to TD.
    The well encountered good quality sandstone reservoirs of Early Jurassic and Late Triassic age. These reservoirs were water bearing with minor amounts of residual hydrocarbons indicated on the logs. The uppermost part of the sandstone interval, 2546 - 2570 m had the highest reservoir quality encountered in the well. Porosities ranged from 15-30% (20.6% average in net sand) with a net/gross sand ratio of 0.85 and an average SW of 90%. The unit ranged from Sinemurian to Pliensbachian in age and consisted of massive to thinly bedded, very fine to fine grained sandstones with interbeds and stringers of shale, siltstone and limestone. Below 2570 m the sandstone units tended generally coarser grained and exhibited fining upward sequences with reduced porosity and net/gross ratio. The only recorded oil show in the well was on core no 1 at 2559.7 m to 2560.9 m. No significant mud gas levels were recorded. The Late Jurassic shales and the Early Jurassic coals and carbonaceous shales are rich source rocks for oil and gas. However, the Late Jurassic shales are immature in the well while the Early Jurassic sequence below ca 2800 m have reached only incipient oil window maturity (vitrinite reflectance ca 0.5% Ro).
    One RFT run was made in the Tilje and Åre Formations and 21 formation pressure reading were taken. A water gradient of 0.099 bar/m (1.01 g/cm3) was calculated. No fluid sample was taken. Two conventional cores were cut, one from 2548.0 m to 2566.55 m in the top of the Tilje Formation and the other from 2717.0 m to 2735.0 m in the base of the Tilje Formation
    The well was permanently abandoned on 7 July 1983 as a dry hole.
    Testing
    No drill stem test was performed.
  • 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]
    340.00
    3067.00
  • 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
    2548.0
    2566.5
    [m ]
    2
    2717.0
    2735.0
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    36.5
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES
  • Core photos

    Core photos
    Core photo at depth: 2548-2552m
    Core photo at depth: 2552-2556m
    Core photo at depth: 2556-2560m
    Core photo at depth: 2560-2564m
    Core photo at depth: 2564-2566m
    2548-2552m
    2552-2556m
    2556-2560m
    2560-2564m
    2564-2566m
    Core photo at depth: 2717-2721m
    Core photo at depth: 2721-2725m
    Core photo at depth: 2725-2729m
    Core photo at depth: 2729-2733m
    Core photo at depth: 2733-2734m
    2717-2721m
    2721-2725m
    2725-2729m
    2729-2733m
    2733-2734m
  • Palynological slides at the Norwegian Offshore Directorate

    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1000.0
    [m]
    DC
    OD
    1100.0
    [m]
    DC
    OD
    1180.0
    [m]
    DC
    OD
    1190.0
    [m]
    DC
    OD
    1200.0
    [m]
    DC
    OD
    1210.0
    [m]
    DC
    OD
    1220.0
    [m]
    DC
    OD
    1230.0
    [m]
    DC
    OD
    1240.0
    [m]
    DC
    OD
    1250.0
    [m]
    DC
    OD
    1260.0
    [m]
    DC
    OD
    1270.0
    [m]
    DC
    OD
    1280.0
    [m]
    DC
    OD
    1290.0
    [m]
    DC
    OD
    1300.0
    [m]
    DC
    OD
    1305.0
    [m]
    DC
    OD
    1310.0
    [m]
    DC
    OD
    1325.0
    [m]
    DC
    OD
    1335.0
    [m]
    DC
    OD
    1345.0
    [m]
    DC
    OD
    1350.0
    [m]
    DC
    OD
    1355.0
    [m]
    DC
    OD
    1365.0
    [m]
    DC
    OD
    1375.0
    [m]
    DC
    OD
    1385.0
    [m]
    DC
    OD
    1395.0
    [m]
    DC
    OD
    1400.0
    [m]
    DC
    OD
    1410.0
    [m]
    DC
    OD
    1430.0
    [m]
    DC
    OD
    1450.0
    [m]
    DC
    OD
    1465.0
    [m]
    DC
    OD
    1480.0
    [m]
    DC
    OD
    1500.0
    [m]
    DC
    OD
    1530.0
    [m]
    DC
    OD
    1550.0
    [m]
    DC
    OD
    1575.0
    [m]
    DC
    OD
    1600.0
    [m]
    DC
    OD
    1630.0
    [m]
    DC
    APT
    1650.0
    [m]
    DC
    OD
    1670.0
    [m]
    DC
    APT
    1680.0
    [m]
    DC
    OD
    1700.0
    [m]
    DC
    OD
    1750.0
    [m]
    DC
    OD
    1770.0
    [m]
    DC
    APT
    1775.0
    [m]
    DC
    RRI
    1795.0
    [m]
    SWC
    RRI
    1800.0
    [m]
    DC
    OD
    1810.0
    [m]
    DC
    RRI
    1830.0
    [m]
    SWC
    RRI
    1835.0
    [m]
    DC
    OD
    1845.0
    [m]
    DC
    OD
    1851.0
    [m]
    SWC
    RRI
    1855.0
    [m]
    DC
    OD
    1865.0
    [m]
    DC
    OD
    1867.0
    [m]
    DC
    OD
    1882.0
    [m]
    DC
    RRI
    1897.0
    [m]
    DC
    OD
    1912.0
    [m]
    DC
    RRI
    1925.0
    [m]
    DC
    RRI
    1925.0
    [m]
    DC
    OD
    1933.0
    [m]
    DC
    RRI
    1935.0
    [m]
    DC
    RRI
    1942.0
    [m]
    DC
    RRI
    1950.0
    [m]
    DC
    RRI
    1950.0
    [m]
    SWC
    RRI
    1955.0
    [m]
    DC
    RRI
    1955.0
    [m]
    DC
    OD
    1966.0
    [m]
    SWC
    RRI
    1972.0
    [m]
    DC
    RRI
    1985.0
    [m]
    DC
    OD
    1987.0
    [m]
    DC
    RRI
    1991.0
    [m]
    SWC
    RRI
    2002.0
    [m]
    DC
    RRI
    2011.0
    [m]
    SWC
    RRI
    2012.0
    [m]
    DC
    RRI
    2015.0
    [m]
    DC
    OD
    2017.0
    [m]
    DC
    RRI
    2032.0
    [m]
    DC
    RRI
    2034.0
    [m]
    SWC
    RRI
    2035.0
    [m]
    DC
    RRI
    2050.0
    [m]
    DC
    RRI
    2054.0
    [m]
    SWC
    RRI
    2060.0
    [m]
    SWC
    RRI
    2062.0
    [m]
    DC
    RRI
    2065.0
    [m]
    DC
    RRI
    2065.0
    [m]
    SWC
    RRI
    2065.0
    [m]
    DC
    OD
    2071.0
    [m]
    SWC
    RRI
    2075.0
    [m]
    DC
    RRI
    2080.0
    [m]
    DC
    RRI
    2080.0
    [m]
    DC
    OD
    2095.0
    [m]
    DC
    RRI
    2100.0
    [m]
    DC
    RRI
    2100.0
    [m]
    SWC
    RRI
    2110.0
    [m]
    DC
    RRI
    2115.0
    [m]
    DC
    OD
    2115.0
    [m]
    DC
    OD
    2125.0
    [m]
    DC
    RRI
    2126.0
    [m]
    SWC
    RRI
    2140.0
    [m]
    DC
    RRI
    2140.0
    [m]
    SWC
    RRI
    2155.0
    [m]
    DC
    RRI
    2165.0
    [m]
    DC
    OD
    2170.0
    [m]
    DC
    RRI
    2179.0
    [m]
    SWC
    RRI
    2180.0
    [m]
    DC
    RRI
    2180.0
    [m]
    DC
    OD
    2195.0
    [m]
    DC
    RRI
    2200.0
    [m]
    DC
    RRI
    2200.0
    [m]
    SWC
    RRI
    2210.0
    [m]
    DC
    RRI
    2212.0
    [m]
    SWC
    RRI
    2215.0
    [m]
    DC
    OD
    2220.0
    [m]
    DC
    OD
    2224.5
    [m]
    SWC
    RRI
    2227.0
    [m]
    DC
    RRI
    2231.0
    [m]
    SWC
    RRI
    2240.0
    [m]
    DC
    OD
    2241.5
    [m]
    SWC
    RRI
    2242.0
    [m]
    DC
    RRI
    2254.0
    [m]
    SWC
    RRI
    2257.0
    [m]
    DC
    RRI
    2265.0
    [m]
    DC
    OD
    2272.0
    [m]
    DC
    RRI
    2284.0
    [m]
    SWC
    RRI
    2287.0
    [m]
    DC
    RRI
    2290.0
    [m]
    DC
    OD
    2302.0
    [m]
    DC
    RRI
    2315.0
    [m]
    DC
    OD
    2317.0
    [m]
    DC
    RRI
    2332.0
    [m]
    DC
    RRI
    2347.0
    [m]
    DC
    RRI
    2354.0
    [m]
    SWC
    RRI
    2362.0
    [m]
    DC
    RRI
    2365.0
    [m]
    DC
    OD
    2377.0
    [m]
    DC
    RRI
    2380.0
    [m]
    DC
    OD
    2385.0
    [m]
    SWC
    RRI
    2392.0
    [m]
    DC
    RRI
    2410.0
    [m]
    DC
    OD
    2415.0
    [m]
    DC
    OD
    2417.0
    [m]
    SWC
    RRI
    2437.0
    [m]
    DC
    RRI
    2440.0
    [m]
    DC
    OD
    2446.0
    [m]
    SWC
    RRI
    2452.0
    [m]
    DC
    RRI
    2465.0
    [m]
    DC
    OD
    2467.0
    [m]
    DC
    RRI
    2480.0
    [m]
    DC
    OD
    2482.0
    [m]
    DC
    RRI
    2486.5
    [m]
    SWC
    RRI
    2495.0
    [m]
    DC
    RRI
    2512.0
    [m]
    DC
    RRI
    2515.0
    [m]
    DC
    OD
    2519.0
    [m]
    SWC
    RRI
    2527.0
    [m]
    DC
    RRI
    2530.0
    [m]
    DC
    OD
    2535.5
    [m]
    SWC
    RRI
    2542.0
    [m]
    DC
    RRI
    2549.9
    [m]
    C
    RRI
    2550.0
    [m]
    DC
    OD
    2563.8
    [m]
    C
    RRI
    2565.2
    [m]
    C
    RRI
    2575.0
    [m]
    DC
    OD
    2591.0
    [m]
    SWC
    RRI
    2600.0
    [m]
    DC
    OD
    2607.0
    [m]
    SWC
    RRI
    2632.0
    [m]
    DC
    RRI
    2647.0
    [m]
    DC
    RRI
    2650.0
    [m]
    DC
    OD
    2662.0
    [m]
    DC
    RRI
    2677.0
    [m]
    DC
    RRI
    2682.0
    [m]
    SWC
    RRI
    2690.0
    [m]
    DC
    RRI
    2700.0
    [m]
    DC
    OD
    2702.0
    [m]
    DC
    RRI
    2717.0
    [m]
    DC
    RRI
    2719.2
    [m]
    C
    RRI
    2727.0
    [m]
    DC
    RRI
    2729.3
    [m]
    C
    RRI
    2734.1
    [m]
    C
    RRI
    2737.0
    [m]
    DC
    RRI
    2750.0
    [m]
    DC
    OD
    2752.0
    [m]
    DC
    RRI
    2767.0
    [m]
    DC
    RRI
    2775.0
    [m]
    DC
    OD
    2780.0
    [m]
    DC
    RRI
    2797.0
    [m]
    DC
    RRI
    2800.0
    [m]
    DC
    OD
    2812.0
    [m]
    DC
    RRI
    2842.0
    [m]
    DC
    RRI
    2850.0
    [m]
    DC
    OD
    2857.0
    [m]
    DC
    RRI
    2872.0
    [m]
    DC
    RRI
    2887.0
    [m]
    DC
    RRI
    2900.0
    [m]
    DC
    OD
    2901.0
    [m]
    SWC
    RRI
    2902.0
    [m]
    DC
    RRI
    2917.0
    [m]
    DC
    RRI
    2922.0
    [m]
    DC
    OD
    2932.0
    [m]
    DC
    RRI
    2947.0
    [m]
    DC
    RRI
    2950.5
    [m]
    SWC
    RRI
    2962.0
    [m]
    DC
    RRI
    2973.0
    [m]
    SWC
    RRI
    2977.0
    [m]
    DC
    RRI
    2992.0
    [m]
    DC
    RRI
    3005.0
    [m]
    DC
    RRI
    3005.0
    [m]
    SWC
    RRI
    3015.0
    [m]
    DC
    RRI
    3052.0
    [m]
    DC
    RRI
    3059.5
    [m]
    SWC
    RRI
    3067.0
    [m]
    DC
    RRI
  • Lithostratigraphy

  • Geochemical information

    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.22
    pdf
    5.94
  • 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
    11.50
  • Logs

    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL VDL
    600
    1849
    CST
    1217
    1857
    CST
    1933
    2486
    CST
    2159
    3059
    HDT
    1200
    1857
    ISF LSS GR SP
    260
    1863
    ISF LSS GR SP MSFL
    1849
    3067
    LDT CNL GR CAL
    323
    3067
    RFT
    2554
    3039
    SHDT
    1849
    3067
    VELOCITY
    510
    3044
  • 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
    325.0
    36
    332.0
    0.00
    LOT
    SURF.COND.
    20
    896.0
    26
    915.0
    1.58
    LOT
    INTERM.
    13 3/8
    1849.0
    17 1/2
    1864.0
    2.00
    LOT
    OPEN HOLE
    3068.0
    12 1/4
    3068.0
    0.00
    LOT
  • Drilling mud

    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    332
    1.05
    100.0
    spud mud
    915
    1.07
    43.0
    11.0
    water based
    1864
    1.32
    70.0
    22.0
    water based
    1864
    1.30
    53.0
    18.0
    water based
    2230
    1.30
    60.0
    19.0
    water based
    2566
    1.31
    59.0
    19.0
    water based
    2877
    1.30
    54.0
    28.0
    water based
    3068
    1.30
    54.0
    28.0
    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