Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
21.11.2024 - 01:28
Time of last synchronization with Norwegian Offshore Directorate's internal systems

7120/2-3 S

Export: PDF icon PDF

  • General information
    General information
    Attribute Value
    Wellbore name
    Official name of wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    7120/2-3 S
    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.
    BARENTS 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.
    7120/2-3
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    LN10M03-inline 14484 & crossline 12293
    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.
    Lundin Norway 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.
    1353-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.
    56
    Entered date
    The date when he wellbore was spudded. For sidetracks: The date when new formation was drilled by kicking off from the mother-wellbore,
    15.05.2011
    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.
    09.07.2011
    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.
    09.07.2013
    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.
    10.08.2013
    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.
    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.
    EARLY CRETACEOUS
    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.
    KOLMULE FM
    2nd level with HC, age
    Age of lithostratigraphic unit, 2nd level, where hydrocarbons were encountered. Examples of legal values: CRETACEOUS, EARLY CRETACEOUS, LATE JURASSIC, EOCENE.
    EARLY CRETACEOUS
    2nd level with HC, formation
    Name of lithostartigraphic unit, 2nd level, where hydrocarbons were encountered. Shown only for released wells. Examples of legal values: BASEMENT, COOK FM, EKOFISK FM, HEIMDAL FM, SANDNES FM, SOGNEFJORD FM, TARBERT FM, BRENT GP.
    KNURR FM
    3rd level with HC, age
    Age of lithostratigraphic unit, 3rd level, where hydrocarbons were encountered. Examples of legal values: CRETACEOUS, EARLY CRETACEOUS, LATE JURASSIC, EOCENE.
    MIDDLE JURASSIC
    3rd level with HC, formation
    Name of lithostartigraphic unit, 3rd 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.
    STØ 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.
    312.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2625.0
    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).
    2620.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    5.3
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    93
    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.
    SNADD FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    71° 47' 20.97'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    20° 21' 44.23'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7965749.13
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    477755.39
    UTM zone
    Universal Transverse Mercator zone. Examples of legal values: 31, 32, 33, 34.
    34
    NPDID wellbore
    Norwegian Offshore Directorate's unique id for the wellbore.
    6592

  • Wellbore history
    General
    The 7120/2-3 S well was drilled on the Skalle prospect north-west of the Snøhvit Field at a location between the Loppa High to the north and the Hammerfest Basin south. The objective was to explore the reservoir potential of the Mesozoic succession, with sandstones of the Kolmule and Stø Formations as the primary target.
    Operations and results
    A 9 7/8" pilot hole, named 7120/2-U-1 was drilled to 655 m to check for shallow gas. None was encountered. Wildcat well 7120/2-3 was spudded with the semi-submersible installation Transocean Leader on 15 May 2011 and drilled to TD at 2625 m (2620 m TVD) in the Late Triassic Snadd Formation. No significant problem was encountered in the operations. The well was drilled with seawater and sweeps down to 650 m and with KCL/polymer/GEM mud from 650 m to TD. In the 17 1/2" section from 650 m to 1522 m mud from the recent 7220/8-1 Skrugard well was re-used in this well. This mud proved to contain oil that made shows evaluation difficult and was replaced before drilling the next section.
    The well encountered hydrocarbons at three stratigraphic levels; a gas column from 1576 m to a free gas-water contact at 1639.4 m in the Early Cretaceous Kolmule Formation, gas in a down-to situation in the Early Cretaceous Knurr Formation, and a gas column from 2071 m to a free gas-water contact at 2095.9 m in the Early to Middle Jurassic, Stø Formation. The Kolmule reservoir had a gross thickness of 150 m, consisting of several sandstone bodies with reservoir facies ranging from shallow marine sandstones to conglomerates and homogenous slope turbidites. The Knurr Formation reservoir was a 5 m thick partly carbonate cemented sandstone resting on the Hekkingen Formation. The Stø reservoir consisted of 149 m thick, clean sandstone. Water bearing sandstone reservoirs were also present in the Tubåen, Fruholmen, and Snadd formation. The reservoir quality in the sandstones from Stø level and down was affected by quartz diagenesis. Due to interference from the mud system oil shows were difficult. However minor oil shows were recorded in intervals on the cores from all three gas bearing reservoir sections. In addition, above average gas levels (3 to 3.5 % Total Gas) were observed through the upper Nordmela Formation in the interval from 2220 to 2255 m, and these had a high level of heavy components.
    A total of 9 conventional cores were cut, 4 from 1583 to 1639 m in the Kolmule Formation sandstone, 2 from 2002 m to 2025 m in the Hekkingen and Fuglen Formations, and 3 from 2074.8 m to 2170 m in the Stø Formation sandstones. Depth shifts to match with logs were -2.3 m for the cores 1 to 4, -2.9 to -4.0 m for cores 5 and 6, +0.45 m for core 7, and no shift for cores 8 and 9. MDT fluid samples were taken at 1585.5 m (gas) and 1635 (gas) m, and 1664.8 m (water) in the Kolmule Formation, 1998.9 m (gas) in the lower Knurr Formation, 2079 m (gas) in the Stø Formation, and 2139 m (water) in the Stø Formation.
    The well was permanently abandoned on 9 July 2011 as a gas discovery.
    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]
    660.00
    2625.00

  • 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
    1583.0
    1595.7
    [m ]
    2
    1596.0
    1611.0
    [m ]
    3
    1612.1
    1627.5
    [m ]
    4
    1628.0
    1638.6
    [m ]
    5
    2002.0
    2016.4
    [m ]
    6
    2016.5
    2024.7
    [m ]
    7
    2074.8
    2101.2
    [m ]
    8
    2101.8
    2157.3
    [m ]
    9
    2156.0
    2169.0
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    171.1
    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
    660.0
    [m]
    DC
    ROBERT
    700.0
    [m]
    DC
    ROBERT
    740.0
    [m]
    DC
    ROBERT
    780.0
    [m]
    DC
    ROBERT
    820.0
    [m]
    DC
    ROBERT
    860.0
    [m]
    DC
    ROBERT
    900.0
    [m]
    DC
    ROBERT
    940.0
    [m]
    DC
    ROBERT
    980.0
    [m]
    DC
    ROBERT
    1020.0
    [m]
    DC
    ROBERT
    1060.0
    [m]
    DC
    ROBERT
    1100.0
    [m]
    DC
    ROBERT
    1140.0
    [m]
    DC
    ROBERT
    1180.0
    [m]
    DC
    ROBERT
    1220.0
    [m]
    DC
    ROBERT
    1260.0
    [m]
    DC
    ROBERT
    1300.0
    [m]
    DC
    ROBERT
    1340.0
    [m]
    DC
    ROBERT
    1380.0
    [m]
    DC
    ROBERT
    1420.0
    [m]
    DC
    ROBERT
    1430.0
    [m]
    DC
    ROBERT
    1440.0
    [m]
    DC
    ROBERT
    1450.0
    [m]
    DC
    ROBERT
    1460.0
    [m]
    DC
    ROBERT
    1470.0
    [m]
    DC
    ROBERT
    1480.0
    [m]
    DC
    ROBERT
    1490.0
    [m]
    DC
    ROBERT
    1500.0
    [m]
    DC
    ROBERT
    1510.0
    [m]
    DC
    ROBERT
    1520.0
    [m]
    DC
    ROBERT
    1530.0
    [m]
    DC
    ROBERT
    1540.0
    [m]
    DC
    ROBERT
    1550.0
    [m]
    DC
    ROBERT
    1560.0
    [m]
    DC
    ROBERT
    1570.0
    [m]
    DC
    ROBERT
    1583.4
    [m]
    C
    ROBERT
    1584.7
    [m]
    C
    ROBERT
    1585.3
    [m]
    C
    ROBERT
    1587.5
    [m]
    C
    ROBERT
    1589.5
    [m]
    C
    ROBERT
    1590.3
    [m]
    C
    ROBERT
    1590.7
    [m]
    C
    ROBERT
    1592.3
    [m]
    C
    ROBERT
    1595.4
    [m]
    C
    ROBERT
    1596.7
    [m]
    C
    ROBERT
    1598.6
    [m]
    C
    ROBERT
    1599.5
    [m]
    C
    ROBERT
    1601.4
    [m]
    C
    ROBERT
    1603.7
    [m]
    C
    ROBERT
    1604.4
    [m]
    C
    ROBERT
    1605.6
    [m]
    C
    ROBERT
    1606.7
    [m]
    C
    ROBERT
    1608.7
    [m]
    C
    ROBERT
    1610.7
    [m]
    C
    ROBERT
    1613.5
    [m]
    C
    ROBERT
    1616.3
    [m]
    C
    ROBERT
    1616.5
    [m]
    C
    ROBERT
    1620.3
    [m]
    C
    ROBERT
    1621.6
    [m]
    C
    ROBERT
    1622.2
    [m]
    C
    ROBERT
    1623.7
    [m]
    C
    ROBERT
    1624.5
    [m]
    C
    ROBERT
    1625.9
    [m]
    C
    ROBERT
    1626.4
    [m]
    C
    ROBERT
    1627.3
    [m]
    C
    ROBERT
    1628.9
    [m]
    C
    ROBERT
    1629.8
    [m]
    C
    ROBERT
    1630.0
    [m]
    C
    ROBERT
    1632.1
    [m]
    C
    ROBERT
    1633.8
    [m]
    C
    ROBERT
    1634.4
    [m]
    C
    ROBERT
    1635.1
    [m]
    C
    ROBERT
    1635.9
    [m]
    C
    ROBERT
    1636.6
    [m]
    C
    ROBERT
    1637.0
    [m]
    C
    ROBERT
    1638.3
    [m]
    C
    ROBERT
    1642.0
    [m]
    DC
    ROBERT
    1651.0
    [m]
    DC
    ROBERT
    1657.0
    [m]
    DC
    ROBERT
    1660.0
    [m]
    DC
    ROBERT
    1669.0
    [m]
    DC
    ROBERT
    1678.0
    [m]
    DC
    ROBERT
    1687.0
    [m]
    DC
    ROBERT
    1696.0
    [m]
    DC
    ROBERT
    1705.0
    [m]
    DC
    ROBERT
    1714.0
    [m]
    DC
    ROBERT
    1723.0
    [m]
    DC
    ROBERT
    1732.0
    [m]
    DC
    ROBERT
    1741.0
    [m]
    DC
    ROBERT
    1759.0
    [m]
    DC
    ROBERT
    1768.0
    [m]
    DC
    ROBERT
    1777.0
    [m]
    DC
    ROBERT
    1786.0
    [m]
    DC
    ROBERT
    1795.0
    [m]
    DC
    ROBERT
    1804.0
    [m]
    DC
    ROBERT
    1813.0
    [m]
    DC
    ROBERT
    1822.0
    [m]
    DC
    ROBERT
    1831.0
    [m]
    DC
    ROBERT
    1840.0
    [m]
    DC
    ROBERT
    1849.0
    [m]
    DC
    ROBERT
    1858.0
    [m]
    DC
    ROBERT
    1867.0
    [m]
    DC
    ROBERT
    1876.0
    [m]
    DC
    ROBERT
    1885.0
    [m]
    DC
    ROBERT
    1894.0
    [m]
    DC
    ROBERT
    1903.0
    [m]
    DC
    ROBERT
    1912.0
    [m]
    DC
    ROBERT
    1921.0
    [m]
    DC
    ROBERT
    1930.0
    [m]
    DC
    ROBERT
    1939.0
    [m]
    DC
    ROBERT
    1948.0
    [m]
    DC
    ROBERT
    1966.0
    [m]
    DC
    ROBERT
    1975.0
    [m]
    DC
    ROBERT
    1984.0
    [m]
    DC
    ROBERT
    1993.0
    [m]
    DC
    ROBERT
    2002.0
    [m]
    C
    ROBERT
    2002.3
    [m]
    C
    ROBERT
    2002.7
    [m]
    C
    ROBERT
    2004.7
    [m]
    C
    ROBERT
    2006.9
    [m]
    C
    ROBERT
    2009.4
    [m]
    C
    ROBERT
    2010.7
    [m]
    C
    ROBERT
    2012.5
    [m]
    C
    ROBERT
    2015.5
    [m]
    C
    ROBERT
    2017.7
    [m]
    C
    ROBERT
    2019.1
    [m]
    C
    ROBERT
    2019.4
    [m]
    C
    ROBERT
    2020.4
    [m]
    C
    ROBERT
    2020.9
    [m]
    C
    ROBERT
    2021.9
    [m]
    C
    ROBERT
    2022.5
    [m]
    C
    ROBERT
    2024.7
    [m]
    C
    ROBERT
    2029.0
    [m]
    DC
    ROBERT
    2038.0
    [m]
    DC
    ROBERT
    2047.0
    [m]
    DC
    ROBERT
    2056.0
    [m]
    DC
    ROBERT
    2065.0
    [m]
    DC
    ROBERT
    2074.0
    [m]
    DC
    ROBERT
    2075.2
    [m]
    C
    ROBERT
    2076.5
    [m]
    C
    ROBERT
    2077.2
    [m]
    C
    ROBERT
    2080.8
    [m]
    C
    ROBERT
    2086.7
    [m]
    C
    ROBERT
    2087.5
    [m]
    C
    ROBERT
    2091.3
    [m]
    C
    ROBERT
    2091.6
    [m]
    C
    ROBERT
    2092.7
    [m]
    C
    ROBERT
    2095.9
    [m]
    C
    ROBERT
    2098.5
    [m]
    C
    ROBERT
    2102.5
    [m]
    C
    ROBERT
    2104.5
    [m]
    C
    ROBERT
    2105.8
    [m]
    C
    ROBERT
    2106.1
    [m]
    C
    ROBERT
    2106.3
    [m]
    C
    ROBERT
    2106.8
    [m]
    C
    ROBERT
    2108.8
    [m]
    C
    ROBERT
    2110.0
    [m]
    DC
    ROBERT
    2110.7
    [m]
    C
    ROBERT
    2113.5
    [m]
    C
    ROBERT
    2115.8
    [m]
    C
    ROBERT
    2116.6
    [m]
    C
    ROBERT
    2118.4
    [m]
    C
    ROBERT
    2119.5
    [m]
    C
    ROBERT
    2119.8
    [m]
    C
    ROBERT
    2120.5
    [m]
    C
    ROBERT
    2120.5
    [m]
    C
    ROBERT
    2120.7
    [m]
    C
    ROBERT
    2121.0
    [m]
    C
    ROBERT
    2122.7
    [m]
    C
    ROBERT
    2127.7
    [m]
    C
    ROBERT
    2132.9
    [m]
    C
    ROBERT
    2134.5
    [m]
    C
    ROBERT
    2139.6
    [m]
    C
    ROBERT
    2146.3
    [m]
    C
    ROBERT
    2152.0
    [m]
    C
    ROBERT
    2153.1
    [m]
    C
    ROBERT
    2155.9
    [m]
    C
    ROBERT
    2156.7
    [m]
    C
    ROBERT
    2159.8
    [m]
    C
    ROBERT
    2165.5
    [m]
    C
    ROBERT
    2167.9
    [m]
    C
    ROBERT
    2173.0
    [m]
    DC
    ROBERT
    2182.0
    [m]
    DC
    ROBERT
    2191.0
    [m]
    DC
    ROBERT
    2200.0
    [m]
    DC
    ROBERT
    2209.0
    [m]
    DC
    ROBERT
    2227.0
    [m]
    DC
    ROBERT
    2236.0
    [m]
    DC
    ROBERT
    2245.0
    [m]
    DC
    ROBERT
    2254.0
    [m]
    DC
    ROBERT
    2263.0
    [m]
    DC
    ROBERT
    2272.0
    [m]
    DC
    ROBERT
    2281.0
    [m]
    DC
    ROBERT
    2290.0
    [m]
    DC
    ROBERT
    2299.0
    [m]
    DC
    ROBERT
    2308.0
    [m]
    DC
    ROBERT
    2317.0
    [m]
    DC
    ROBERT
    2326.0
    [m]
    DC
    ROBERT
    2335.0
    [m]
    DC
    ROBERT
    2344.0
    [m]
    DC
    ROBERT
    2353.0
    [m]
    DC
    ROBERT
    2362.0
    [m]
    DC
    ROBERT
    2371.0
    [m]
    DC
    ROBERT
    2380.0
    [m]
    DC
    ROBERT
    2389.0
    [m]
    DC
    ROBERT
    2398.0
    [m]
    DC
    ROBERT
    2407.0
    [m]
    DC
    ROBERT
    2416.0
    [m]
    DC
    ROBERT
    2425.0
    [m]
    DC
    ROBERT
    2434.0
    [m]
    DC
    ROBERT
    2443.0
    [m]
    DC
    ROBERT
    2452.0
    [m]
    DC
    ROBERT
    2461.0
    [m]
    DC
    ROBERT
    2470.0
    [m]
    DC
    ROBERT
    2479.0
    [m]
    DC
    ROBERT
    2497.0
    [m]
    DC
    ROBERT
    2506.0
    [m]
    DC
    ROBERT
    2524.0
    [m]
    DC
    ROBERT
    2533.0
    [m]
    DC
    ROBERT
    2551.0
    [m]
    DC
    ROBERT
    2560.0
    [m]
    DC
    ROBERT
    2569.0
    [m]
    DC
    ROBERT
    2578.0
    [m]
    DC
    ROBERT
    2587.0
    [m]
    DC
    ROBERT
    2596.0
    [m]
    DC
    ROBERT
    2605.0
    [m]
    DC
    ROBERT
    2614.0
    [m]
    DC
    ROBERT
    2623.0
    [m]
    DC
    ROBERT

  • Lithostratigraphy

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CMR XPT
    1533
    2030
    CMR XPT
    2215
    2592
    FMI MSIP
    1514
    2031
    FMI MSIP
    2033
    2626
    HRLA PEX ECS HNGS
    1514
    2020
    HRLA PEX ECS HNGS
    2033
    2653
    MDT GR
    1587
    1997
    MDT GR
    2073
    2154
    MSCT GR
    1550
    2000
    MSCT GR
    2045
    2582
    MSCT GR
    2298
    2601
    MSIP
    1000
    1514
    MSIP
    1450
    2033
    MWD - GR RES PWD
    0
    0
    MWD - NBGR GR RES PWD SON DIR PW
    643
    1510
    MWD - NBGR GR RES SON DEN NEU PW
    1514
    2026
    MWD - NBGR NBRES GR RES SON DEN
    2034
    2624
    USIT GR
    1000
    1510
    USIT GR
    1450
    2033
    VSI GR
    338
    2615

  • 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
    394.0
    36
    394.0
    0.00
    LOT
    SURF.COND.
    20
    642.0
    26
    650.0
    1.55
    LOT
    INTERM.
    13 3/8
    1515.0
    17 1/2
    1522.0
    1.76
    LOT
    INTERM.
    9 5/8
    2034.0
    12 1/4
    2036.0
    2.04
    LOT
    OPEN HOLE
    2625.0
    8 1/2
    2615.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    650
    1.14
    8.0
    KCl/Polymer/GEM
    688
    1.15
    8.0
    KCl/Polymer/GEM
    1015
    1.17
    13.0
    KCl/Polymer/GEM
    1268
    1.17
    14.0
    KCl/Polymer/GEM
    1507
    1.18
    16.0
    KCl/Polymer/GEM
    1522
    1.21
    16.0
    KCl/Polymer/GEM
    1522
    1.18
    15.0
    KCl/Polymer/GEM
    1583
    1.21
    17.0
    KCl/Polymer/GEM
    1700
    1.21
    18.0
    KCl/Polymer/GEM
    2024
    1.21
    20.0
    KCl/Polymer/GEM
    2100
    1.20
    16.0
    KCl/Polymer/GEM
    2112
    1.21
    19.0
    KCl/Polymer/GEM
    2259
    1.17
    16.0
    KCl/Polymer/GEM
    2625
    1.15
    18.0
    KCl/Polymer/GEM

  • 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