Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
23.11.2024 - 01:30
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16/2-5

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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.
    16/2-5
    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
    Press release
    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
    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.
    16/2-5
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    3D survey SNST3D-inline 3589 & crossline 5365
    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.
    StatoilHydro Petroleum 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.
    1227-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.
    81
    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,
    22.02.2009
    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.
    13.05.2009
    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.
    13.05.2011
    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.
    13.05.2011
    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.
    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.
    UNDEFINED GP
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    49.2
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    109.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2373.0
    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).
    2373.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    2.8
    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.
    PRE-DEVONIAN
    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.
    BASEMENT
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    58° 48' 50.74'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 22' 11.05'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6519672.84
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    463593.42
    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.
    6042

  • Wellbore history
    General
    Well 16/2-5 was drilled on the Ragnarock III prospect on the Utsira High in the North Sea. The primary objective of the well was to prove the presence of hydrocarbons in the pre-BCU interval and establish the composition and age of the sediments. The secondary target was the chalk in the Ekofisk and Tor Formations of Late Cretaceous age. The presence of hydrocarbons in these formations at the well location was possible, but not expected.
    Operations and results
    Wildcat well 16/2-5 was spudded with the jack-up installation West Epsilon on 22 February 2009 and drilled to TD at 2373 m in pre-Devonian Basement. After drilling the 36" hole to 288 m a 9 7/8" pilot hole was drilled to 513 m to check for shallow gas. No shallow gas or shallow water flow was observed. The well was drilled with spud mud down to 519 m, with KCl/polymer/glycol mud from 519 m to 1747 m, and with KCl/polymer/glycol low-sulphate mud from 1747 m to TD.
    The well penetrated rocks of Quaternary, Tertiary and Cretaceous age, it then penetrated Graben Fill before TD in Basement. Base Cretaceous/top Graben Fill was encountered at 1884 m. A total thickness of 458 m of Graben Fill consisting of coarse, clastic sediments was penetrated and 3 cores were cut from 1894 to 1994 m. Due to lack of fossils no reliable dating was obtained for the Graben Fill. The Graben Fill was gas/condensate filled from top of the reservoir and down to 1902 m. High quality gas condensate samples were acquired by use of wire line sampling tools. A water sample was acquired at 1935 m and oil was scanned at 1916 m MD. An interval with oil was confirmed also by sampling at 1921.5 m, but due to poor pressure measurements in this interval the OWC was only tentatively set at 1917 m based on logs and geochemistry. No oil shows were observed above reservoir level. In the reservoir oil shows were seen down to 1981 m and no shows were seen below this level.
    The well was permanently abandoned on 13 May 2009 as a gas discovery.
    Testing
    A full scale DST was performed in the interval 1885 - 1902 m. The perforated interval was placed in the gas zone with the lowermost interval close to the interpreted GOC. The gas rate for the main flow was 110 000 Sm3/d with a 40/64" choke size. A maximum gas rate of 120 000 Sm3/day was achieved on a 60/64" choke size. The total test production of associated condensate with the gas was about 6 Sm3 mixed with some oil, no water was produced during testing. At top reservoir the formation pressure was 191.8 bar at 1885 m. The bottom hole temperature recorded in the test was 71 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]
    300.00
    2373.00

  • 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
    1894.0
    1947.3
    [m ]
    2
    1948.0
    1966.9
    [m ]
    3
    1967.0
    1992.0
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    97.2
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    600.0
    [m]
    DC
    NETWORK
    620.0
    [m]
    DC
    NETWOR
    645.0
    [m]
    DC
    NETWOR
    660.0
    [m]
    DC
    NETWOR
    680.0
    [m]
    DC
    NETWOR
    700.0
    [m]
    DC
    NETWOR
    720.0
    [m]
    DC
    NETWOR
    740.0
    [m]
    DC
    NETWOR
    760.0
    [m]
    DC
    NETWOR
    780.0
    [m]
    DC
    NETWOR
    800.0
    [m]
    DC
    NETWOR
    810.0
    [m]
    DC
    NETWOR
    820.0
    [m]
    DC
    NETWOR
    830.0
    [m]
    DC
    NETWOR
    840.0
    [m]
    DC
    NETWOR
    850.0
    [m]
    DC
    NETWOR
    860.0
    [m]
    DC
    NETWOR
    870.0
    [m]
    DC
    NETWOR
    880.0
    [m]
    DC
    NETWOR
    890.0
    [m]
    DC
    NETWOR
    900.0
    [m]
    DC
    NETWOR
    910.0
    [m]
    DC
    NETWOR
    920.0
    [m]
    DC
    NETWOR
    930.0
    [m]
    DC
    NETWOR
    940.0
    [m]
    DC
    NETWOR
    950.0
    [m]
    DC
    NETWOR
    960.0
    [m]
    DC
    NETWOR
    970.0
    [m]
    DC
    NETWOR
    980.0
    [m]
    DC
    NETWOR
    990.0
    [m]
    DC
    NETWOR
    1000.0
    [m]
    DC
    NETWOR
    1010.0
    [m]
    DC
    NETWOR
    1020.0
    [m]
    DC
    NETWOR
    1030.0
    [m]
    DC
    NETWOR
    1050.0
    [m]
    DC
    NETWOR
    1070.0
    [m]
    DC
    NETWOR
    1090.0
    [m]
    DC
    NETWOR
    1110.0
    [m]
    DC
    NETWOR
    1130.0
    [m]
    DC
    NETWOR
    1150.0
    [m]
    DC
    NETWOR
    1170.0
    [m]
    DC
    NETWOR
    1190.0
    [m]
    DC
    NETWOR
    1210.0
    [m]
    DC
    NETWOR
    1230.0
    [m]
    DC
    NETWOR
    1250.0
    [m]
    DC
    NETWOR
    1270.0
    [m]
    DC
    NETWOR
    1290.0
    [m]
    DC
    NETWOR
    1310.0
    [m]
    DC
    NETWOR
    1330.0
    [m]
    DC
    NETWOR
    1350.0
    [m]
    DC
    NETWOR
    1370.0
    [m]
    DC
    NETWOR
    1390.0
    [m]
    DC
    NETWOR
    1410.0
    [m]
    DC
    NETWOR
    1430.0
    [m]
    DC
    NETWOR
    1450.0
    [m]
    DC
    NETWOR
    1470.0
    [m]
    DC
    NETWOR
    1490.0
    [m]
    DC
    NETWOR
    1510.0
    [m]
    DC
    NETWOR
    1530.0
    [m]
    DC
    NETWOR
    1550.0
    [m]
    DC
    NETWOR
    1570.0
    [m]
    DC
    NETWOR
    1590.0
    [m]
    DC
    NETWOR
    1610.0
    [m]
    DC
    NETWOR
    1630.0
    [m]
    DC
    NETWOR
    1640.0
    [m]
    DC
    NETWOR
    1650.0
    [m]
    DC
    NETWOR
    1660.0
    [m]
    DC
    NETWOR
    1670.0
    [m]
    DC
    NETWOR
    1680.0
    [m]
    DC
    NETWOR
    1690.0
    [m]
    DC
    NETWOR
    1700.0
    [m]
    DC
    NETWOR
    1710.0
    [m]
    DC
    NETWOR
    1720.0
    [m]
    DC
    NETWOR
    1730.0
    [m]
    DC
    NETWOR
    1740.0
    [m]
    DC
    NETWOR
    1746.0
    [m]
    DC
    NETWOR
    1752.0
    [m]
    DC
    NETWOR
    1761.0
    [m]
    DC
    NETWOR
    1767.0
    [m]
    DC
    NETWOR
    1773.0
    [m]
    DC
    NETWOR
    1779.0
    [m]
    DC
    NETWOR
    1785.0
    [m]
    DC
    NETWOR
    1791.0
    [m]
    DC
    NETWOR
    1800.0
    [m]
    DC
    NETWOR
    1806.0
    [m]
    DC
    NETWOR
    1812.0
    [m]
    DC
    NETWOR
    1818.0
    [m]
    DC
    NETWOR
    1827.0
    [m]
    DC
    NETWOR
    1836.0
    [m]
    DC
    NETWOR
    1842.0
    [m]
    DC
    NETWOR
    1848.0
    [m]
    DC
    NETWOR
    1854.0
    [m]
    DC
    NETWOR
    1860.0
    [m]
    DC
    NETWOR
    1866.0
    [m]
    DC
    NETWOR
    1872.0
    [m]
    DC
    NETWOR
    1878.0
    [m]
    DC
    NETWOR
    1884.0
    [m]
    DC
    NETWOR
    1890.0
    [m]
    DC
    NETWOR
    1895.9
    [m]
    C
    NETWOR
    1899.6
    [m]
    C
    NETWOR
    1901.8
    [m]
    C
    NETWOR
    1907.8
    [m]
    C
    NETWOR
    1915.6
    [m]
    C
    NETWOR
    1916.0
    [m]
    C
    NETWOR
    1919.9
    [m]
    C
    NETWOR
    1922.8
    [m]
    C
    NETWOR
    1930.7
    [m]
    C
    NETWOR
    1941.2
    [m]
    C
    NETWOR
    1948.0
    [m]
    C
    NETWOR
    1953.5
    [m]
    C
    NETWOR
    1962.4
    [m]
    C
    NETWOR
    1965.4
    [m]
    C
    NETWOR
    1965.8
    [m]
    C
    NETWOR
    1966.5
    [m]
    C
    NETWOR
    1967.0
    [m]
    C
    NETWOR
    1971.3
    [m]
    C
    NETWOR
    1973.7
    [m]
    C
    NETWOR
    1979.1
    [m]
    C
    NETWOR
    1983.6
    [m]
    C
    NETWOR
    1987.6
    [m]
    C
    NETWOR
    1989.7
    [m]
    C
    NETWOR
    1995.0
    [m]
    DC
    NETWOR
    2001.0
    [m]
    DC
    NETWOR
    2007.0
    [m]
    DC
    NETWOR
    2013.0
    [m]
    DC
    NETWOR
    2019.0
    [m]
    DC
    NETWOR
    2025.0
    [m]
    DC
    NETWOR
    2031.0
    [m]
    DC
    NETWOR
    2037.0
    [m]
    DC
    NETWOR
    2043.0
    [m]
    DC
    NETWOR
    2049.0
    [m]
    DC
    NETWOR
    2055.0
    [m]
    DC
    NETWOR
    2061.0
    [m]
    DC
    NETWOR
    2067.0
    [m]
    DC
    NETWOR
    2076.0
    [m]
    DC
    NETWOR
    2082.0
    [m]
    DC
    NETWOR
    2088.0
    [m]
    DC
    NETWOR
    2094.0
    [m]
    DC
    NETWOR
    2100.0
    [m]
    DC
    NETWOR
    2106.0
    [m]
    DC
    NETWOR
    2112.0
    [m]
    DC
    NETWOR
    2118.0
    [m]
    DC
    NETWOR
    2124.0
    [m]
    DC
    NETWOR
    2130.0
    [m]
    DC
    NETWOR
    2136.0
    [m]
    DC
    NETWOR
    2142.0
    [m]
    DC
    NETWOR
    2148.0
    [m]
    DC
    NETWOR
    2154.0
    [m]
    DC
    NETWOR
    2160.0
    [m]
    DC
    NETWOR
    2163.0
    [m]
    DC
    NETWOR
    2166.0
    [m]
    DC
    NETWOR
    2169.0
    [m]
    DC
    NETWOR
    2172.0
    [m]
    DC
    NETWOR
    2175.0
    [m]
    DC
    NETWOR
    2178.0
    [m]
    DC
    NETWOR
    2181.0
    [m]
    DC
    NETWOR
    2184.0
    [m]
    DC
    NETWOR
    2187.0
    [m]
    DC
    NETWOR
    2190.0
    [m]
    DC
    NETWOR
    2193.0
    [m]
    DC
    NETWOR
    2196.0
    [m]
    DC
    NETWOR
    2202.0
    [m]
    DC
    NETWOR
    2205.0
    [m]
    DC
    NETWOR
    2208.0
    [m]
    DC
    NETWOR
    2214.0
    [m]
    DC
    NETWOR
    2220.0
    [m]
    DC
    NETWOR
    2226.0
    [m]
    DC
    NETWOR
    2232.0
    [m]
    DC
    NETWOR
    2238.0
    [m]
    DC
    NETWOR
    2244.0
    [m]
    DC
    NETWOR
    2250.0
    [m]
    DC
    NETWOR
    2256.0
    [m]
    DC
    NETWOR
    2262.0
    [m]
    DC
    NETWOR
    2268.0
    [m]
    DC
    NETWOR
    2277.0
    [m]
    DC
    NETWOR
    2283.0
    [m]
    DC
    NETWOR
    2289.0
    [m]
    DC
    NETWOR
    2295.0
    [m]
    DC
    NETWOR
    2301.0
    [m]
    DC
    NETWOR
    2307.0
    [m]
    DC
    NETWOR
    2316.0
    [m]
    DC
    NETWOR
    2328.0
    [m]
    DC
    NETWOR
    2334.0
    [m]
    DC
    NETWOR
    2340.0
    [m]
    DC
    NETWOR

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.48

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    1885
    1902
    23.8
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    19.000
    71
    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
    120000

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CMR HRLA PEX ECS
    1722
    2363
    FMI SONIC SCANNER
    1722
    2363
    MDT PRETEST
    1722
    2340
    MDT-DP VIT-PB MINI DST
    1722
    2030
    MDT-DP VIT-PB MINI DST
    1722
    1899
    MDT-DP VIT-PB SPACING
    1722
    1916
    MSCT
    1722
    2348
    MWD LWD - ARCVRES8 PP
    289
    513
    MWD LWD - ARCVRES9 PP
    289
    1744
    MWD LWD - ARCVRS6 PP
    1880
    2373
    MWD LWD - GVR6 ARCVRES6 PP
    1744
    1894
    PEX HRLT SONIC SCANNER
    157
    1747
    UBI HNGS
    1722
    2350
    ZOVSP
    303
    1717
    ZOVSP
    1399
    2352

  • 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
    281.0
    36
    288.0
    1.10
    LOT
    SURF.COND.
    20
    500.0
    26
    519.0
    1.51
    LOT
    INTERM.
    13 3/8
    1734.0
    17 1/2
    1747.0
    1.60
    LOT
    LINER
    7
    2341.0
    8 1/2
    2373.0
    1.49
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    298
    1.05
    13.0
    Spud Mud
    355
    1.05
    15.0
    Spud Mud
    513
    1.10
    13.0
    Spud Mud
    513
    1.05
    16.0
    Spud Mud
    627
    1.25
    15.0
    KCl/Polymer/GEM
    1695
    1.35
    24.0
    KCl/Polymer/GEM
    1744
    1.37
    22.0
    KCl/Polymer/GEM
    1948
    1.20
    20.0
    KCl/Polymer/Glycol
    2370
    1.20
    22.0
    KCl/Polymer/Glycol
    2373
    1.20
    28.0
    KCl/Polymer/Glycol
    2373
    1.20
    22.0
    KCl/Polymer/Glycol

  • 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