Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
25.11.2024 - 01:30
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24/6-2

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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.
    24/6-2
    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.
    24/6-2
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    NH 9603 INLINE 716 & X-LINE 4914
    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.
    929-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.
    45
    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,
    25.05.1998
    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.
    08.07.1998
    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.
    08.07.2000
    Publication date
    Date quality control of the wellbore information was completed, so it can be published on the internet as a 'Well Data Summary Sheet' wellbore with more information available than other wellbores.
    29.05.2002
    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.
    PALEOCENE
    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.
    HEIMDAL 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.
    124.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2722.0
    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).
    2705.7
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    16.5
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    76
    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.
    PALEOCENE
    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.
    VÅLE FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    59° 33' 32.41'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    1° 57' 17.26'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6602917.98
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    440925.36
    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.
    3397

  • Wellbore history
    General
    Well 24/6-2 was designed to test the hydrocarbon potential of the A2 North Heimdal T60 sand prospect within the Lista Formation in the northern part of the license acreage in block 24/6. A secondary target was defined in the A1 North Hermod T80 sand within the Sele Formation. The well should also test the seismic amplitudes in an area with indications of the presence of the Hermod sand. The well was planned to be drilled to a total depth of 2774 m within the Shetland Group.
    Operations and results
    Well 24/6-2 was drilled with the semi-submersible rig "Transocean Leader". It was spudded on 26 May 1998 and reached a total depth of 2722 m in the Paleocene Våle Formation on 18 June 1998. The well was drilled water based with bentonite mud to 1331 m and with KCl / Polymer mud from 1331 to TD. "BP PCD 208" (polyalkylene glycol) was added to the KCl / Polymer mud from 1802 m to TD (through the 8 1/2" section).
    As TD was set in the Våle Formation the target Shetland Group was not encountered in the well. Both oil and gas were encountered within the Heimdal T60 sand. The gas zone extended from the top of the reservoir at 2099m and down to the oil-gas contact at 2151m (52m gross) and the oil extended down to the oil- water contact at 2168m (17m gross). The reservoir quality is generally excellent, but locally it is reduced either by fines or by calcite cement within what appear to be calcite nodules. The massive channel sands in the upper part of the reservoir confirm the braided channel model used for the T60 sand. Lower down in the reservoir oil zone much more fine material is present as laminations. Some of these units appear as shales on the gamma log, but are in fact fine-grained, argillaceous sands. No Hermod T80 sands were encountered in the well, nor was the "High Acoustic Interval" that was used to map the apparent sand distribution identified on the logs. Twelve cores were cut in the well from 2010 m in the lower part of the Balder Formation Tuff Member, through the Sele Formation and upper Lista Formation shale and down to under the oil-water contact in the Heimdal Formation at 2192 m (182 m in all). Recovery was generally excellent and in some cases over 100% due to gas expansion. The sands in the cores are generally unconsolidated and friable especially in the lower cores. This made plug cutting for core analysis difficult even after core 11 and 12 were frozen. MDT wireline oil samples were collected from 2164 m and 2167 m in the Heimdal Formation.
    The well was permanently plugged and abandoned as an oil and gas discovery on 8 July 1998.
    Testing
    One drill stem test was run in the Heimdal Formation oil zone (perforation 2156.75 - 2165.75 m). The well flowed with a stable flow rate of 550 Sm3/day and 44.000 Sm3/day of gas through a 48/64" choke. Oil density was measured as 0.855 gm/cc. Gas gravity was 0.690 gm/cc and the GOR was 80 Sm3/Sm3. Water was produced during the higher flow rates.

  • 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]
    1340.00
    2195.00

  • 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
    2010.0
    2011.3
    [m ]
    2
    2012.0
    2028.8
    [m ]
    3
    2029.0
    2057.0
    [m ]
    4
    2057.0
    2062.9
    [m ]
    5
    2075.0
    2075.6
    [m ]
    6
    2076.0
    2083.6
    [m ]
    7
    2084.0
    2102.0
    [m ]
    8
    2102.0
    2119.9
    [m ]
    9
    2120.0
    2138.8
    [m ]
    10
    2138.0
    2155.5
    [m ]
    11
    2156.0
    2174.3
    [m ]
    12
    2174.0
    2192.0
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    168.6
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 2010-2011m
    Core photo at depth: 2012-2017m
    Core photo at depth: 2017-2022m
    Core photo at depth: 2022-2027m
    Core photo at depth: 2027-2028m
    2010-2011m
    2012-2017m
    2017-2022m
    2022-2027m
    2027-2028m
    Core photo at depth: 2029-2034m
    Core photo at depth: 2034-2039m
    Core photo at depth: 2039-2044m
    Core photo at depth: 2044-2049m
    Core photo at depth: 2049-2054m
    2029-2034m
    2034-2039m
    2039-2044m
    2044-2049m
    2049-2054m
    Core photo at depth: 2054-2057m
    Core photo at depth: 2057-2062m
    Core photo at depth: 2062-2063m
    Core photo at depth: 2075-2076m
    Core photo at depth: 2076-2081m
    2054-2057m
    2057-2062m
    2062-2063m
    2075-2076m
    2076-2081m
    Core photo at depth: 2081-2083m
    Core photo at depth: 2084-2089m
    Core photo at depth: 2089-2094m
    Core photo at depth: 2094-2099m
    Core photo at depth: 2099-2102m
    2081-2083m
    2084-2089m
    2089-2094m
    2094-2099m
    2099-2102m
    Core photo at depth: 2102-2107m
    Core photo at depth: 2107-2112m
    Core photo at depth: 2112-2117m
    Core photo at depth: 2117-2120m
    Core photo at depth: 2120-2125m
    2102-2107m
    2107-2112m
    2112-2117m
    2117-2120m
    2120-2125m
    Core photo at depth: 2125-2130m
    Core photo at depth: 2130-2135m
    Core photo at depth: 2135-2138m
    Core photo at depth: 2138-2143m
    Core photo at depth: 2143-2148m
    2125-2130m
    2130-2135m
    2135-2138m
    2138-2143m
    2143-2148m
    Core photo at depth: 2148-2153m
    Core photo at depth: 2153-2155m
    Core photo at depth: 2156-2161m
    Core photo at depth: 2161-2166m
    Core photo at depth: 2166-2171m
    2148-2153m
    2153-2155m
    2156-2161m
    2161-2166m
    2166-2171m
    Core photo at depth: 2171-2174m
    Core photo at depth: 2174-2179m
    Core photo at depth: 2179-2184m
    Core photo at depth: 2184-2189m
    Core photo at depth: 2189-2192m
    2171-2174m
    2174-2179m
    2179-2184m
    2184-2189m
    2189-2192m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1400.0
    [m]
    DC
    RRI
    1420.0
    [m]
    DC
    RRI
    1440.0
    [m]
    DC
    RRI
    1460.0
    [m]
    DC
    RRI
    1480.0
    [m]
    DC
    RRI
    1500.0
    [m]
    DC
    RRI
    1520.0
    [m]
    DC
    RRI
    1540.0
    [m]
    DC
    RRI
    1560.0
    [m]
    DC
    RRI
    1580.0
    [m]
    DC
    RRI
    1600.0
    [m]
    DC
    RRI
    1620.0
    [m]
    DC
    RRI
    1640.0
    [m]
    DC
    RRI
    1660.0
    [m]
    DC
    RRI
    1680.0
    [m]
    DC
    RRI
    1700.0
    [m]
    DC
    RRI
    1720.0
    [m]
    DC
    RRI
    1740.0
    [m]
    DC
    RRI
    1760.0
    [m]
    DC
    RRI
    1780.0
    [m]
    DC
    RRI
    1800.0
    [m]
    DC
    RRI
    1817.0
    [m]
    SWC
    RRI
    1822.0
    [m]
    SWC
    RRI
    1831.0
    [m]
    SWC
    RRI
    1842.0
    [m]
    SWC
    RRI
    1850.0
    [m]
    SWC
    RRI
    1859.0
    [m]
    SWC
    RRI
    1869.0
    [m]
    SWC
    RRI
    1881.0
    [m]
    SWC
    RRI
    1892.0
    [m]
    SWC
    RRI
    1899.0
    [m]
    SWC
    RRI
    1901.0
    [m]
    SWC
    RRI
    1910.0
    [m]
    SWC
    RRI
    1920.0
    [m]
    DC
    RRI
    1930.0
    [m]
    SWC
    RRI
    1939.0
    [m]
    SWC
    RRI
    1953.0
    [m]
    SWC
    RRI
    1957.0
    [m]
    SWC
    RRI
    1965.0
    [m]
    SWC
    RRI
    1971.0
    [m]
    SWC
    RRI
    1972.0
    [m]
    DC
    RRI
    1977.0
    [m]
    DC
    RRI
    1981.0
    [m]
    SWC
    RRI
    1987.0
    [m]
    SWC
    RRI
    1992.0
    [m]
    SWC
    RRI
    1994.0
    [m]
    SWC
    RRI
    2000.0
    [m]
    SWC
    RRI
    2000.0
    [m]
    DC
    RRI
    2010.0
    [m]
    C
    RRI
    2014.0
    [m]
    C
    RRI
    2018.0
    [m]
    C
    RRI
    2022.0
    [m]
    C
    RRI
    2026.0
    [m]
    C
    RRI
    2031.0
    [m]
    C
    RRI
    2034.0
    [m]
    C
    RRI
    2038.0
    [m]
    C
    RRI
    2042.0
    [m]
    C
    RRI
    2046.0
    [m]
    C
    RRI
    2050.0
    [m]
    C
    RRI
    2058.0
    [m]
    C
    RRI
    2062.0
    [m]
    C
    RRI
    2078.0
    [m]
    C
    RRI
    2082.0
    [m]
    C
    RRI
    2098.0
    [m]
    C
    RRI
    2117.0
    [m]
    C
    RRI
    2127.0
    [m]
    C
    RRI
    2141.0
    [m]
    C
    RRI
    2147.0
    [m]
    C
    RRI
    2152.0
    [m]
    C
    RRI
    2154.0
    [m]
    C
    RRI
    2156.0
    [m]
    C
    RRI
    2158.0
    [m]
    C
    RRI
    2161.0
    [m]
    C
    RRI
    2162.0
    [m]
    C
    RRI
    2163.0
    [m]
    C
    RRI
    2195.0
    [m]
    DC
    RRI
    2209.0
    [m]
    SWC
    RRI
    2216.0
    [m]
    SWC
    RRI
    2225.0
    [m]
    SWC
    RRI
    2238.0
    [m]
    SWC
    RRI
    2250.0
    [m]
    SWC
    RRI
    2262.0
    [m]
    SWC
    RRI
    2270.0
    [m]
    DC
    RRI
    2281.0
    [m]
    SWC
    RRI
    2327.0
    [m]
    SWC
    RRI
    2344.0
    [m]
    SWC
    RRI
    2347.0
    [m]
    SWC
    RRI
    2362.0
    [m]
    SWC
    RRI
    2370.0
    [m]
    DC
    RRI
    2380.0
    [m]
    DC
    RRI
    2393.0
    [m]
    SWC
    RRI
    2407.0
    [m]
    SWC
    RRI
    2416.0
    [m]
    SWC
    RRI
    2439.0
    [m]
    SWC
    RRI
    2456.0
    [m]
    SWC
    RRI
    2483.0
    [m]
    SWC
    RRI
    2494.0
    [m]
    SWC
    RRI
    2505.0
    [m]
    SWC
    RRI
    2510.0
    [m]
    DC
    RRI
    2521.0
    [m]
    SWC
    RRI
    2530.0
    [m]
    DC
    RRI
    2542.0
    [m]
    SWC
    RRI
    2555.0
    [m]
    SWC
    RRI
    2567.0
    [m]
    SWC
    RRI
    2582.0
    [m]
    SWC
    RRI
    2597.0
    [m]
    SWC
    RRI
    2600.0
    [m]
    DC
    RRI
    2613.0
    [m]
    SWC
    RRI
    2626.0
    [m]
    SWC
    RRI
    2630.0
    [m]
    DC
    RRI
    2648.0
    [m]
    SWC
    RRI
    2659.0
    [m]
    SWC
    RRI
    2670.0
    [m]
    DC
    RRI
    2674.0
    [m]
    SWC
    RRI
    2679.0
    [m]
    SWC
    RRI
    2690.0
    [m]
    SWC
    RRI

  • Oil samples at the Norwegian Offshore Directorate
    Oil samples at the Norwegian Offshore Directorate
    Test type
    Bottle number
    Top depth
    MD [m]
    Bottom depth
    MD [m]
    Fluid type
    Test time
    Samples available
    DST
    TEST1
    2165.75
    2156.75
    30.06.1998 - 16:00
    YES

  • Lithostratigraphy

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    1.99
    pdf
    2.24

  • 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
    1.27
    .pdf
    52.99

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    2166
    2157
    19.0
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    4.800
    18.680
    69
    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
    550
    44000
    0.860
    0.690
    80

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CST GR
    1809
    2720
    FMI NGT
    2720
    2797
    HALS DSI TLD CNL SP GRL GR
    147
    2720
    MDT GR
    2102
    2205
    MWD DPR GR-DIR
    147
    2722
    VSP GR
    1600
    2710

  • 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
    221.0
    36
    221.0
    0.00
    LOT
    INTERM.
    13 3/8
    1326.0
    17 1/2
    1331.0
    0.00
    LOT
    INTERM.
    9 5/8
    1797.0
    12 1/4
    1802.0
    1.81
    LOT
    OPEN HOLE
    2722.0
    8 1/2
    2722.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    488
    1.05
    WATER BASED
    1285
    1.05
    WATER BASED
    1331
    1.05
    WATER BASED
    1429
    1.36
    22.0
    WATER BASED
    1802
    1.36
    25.0
    WATER BASED
    1822
    1.25
    23.0
    WATER BASED
    2010
    1.25
    29.0
    WATER BASED
    2056
    1.26
    26.0
    WATER BASED
    2102
    1.26
    25.0
    WATER BASED
    2138
    1.25
    23.0
    WATER BASED
    2174
    1.25
    22.0
    WATER BASED
    2192
    1.25
    24.0
    WATER BASED
    2303
    1.25
    20.0
    WATER BASED
    2304
    1.25
    20.0
    WATER BASED
    2593
    1.25
    22.0
    WATER BASED
    2722
    0.00
    26.0
    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