Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
22.12.2024 - 01:25
Time of last synchronization with Norwegian Offshore Directorate's internal systems

7220/7-1

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.
    7220/7-1
    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
    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
    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.
    7220/7-1
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    3D survey WG 08STR10 inline 1302 & xline 3123
    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.
    Statoil 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.
    1389-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.
    51
    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,
    05.12.2011
    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.
    24.01.2012
    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.
    24.01.2014
    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.
    11.04.2014
    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.
    MIDDLE 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.
    STØ 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 JURASSIC
    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.
    NORDMELA FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    40.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    365.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2230.0
    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).
    2229.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    6
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    72
    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.
    FRUHOLMEN FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    72° 27' 37.53'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    20° 9' 8.59'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    8047938.73
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    673127.84
    UTM zone
    Universal Transverse Mercator zone. Examples of legal values: 31, 32, 33, 34.
    33
    NPDID wellbore
    Norwegian Offshore Directorate's unique id for the wellbore.
    6756

  • Wellbore history
    General
    Well 7220/7-1 was drilled southwest of the 7220/8-1 Skrugard discovery and west of the Loppa High in the Barents Sea. The targeted Havis fault block is one of several rotated fault blocks in the licence, and a part of the Bjørnøyrenna Fault Complex. The primary objective was to test the hydrocarbon potential in the Stø, Nordmela and Tubåen Formations, all of Jurassic age. Secondary objectives were to test the presence and quality of sandstones in the lower Triassic Fruholmen Formation, as well as to collect data needed for field development purposes. A clear flat event was observed in the seismic at 1960 m. Seismic data also indicated flat events at 1830 m and 2105 m.
    Operations and results
    A pilot hole was drilled on the spud location with seawater and returns to seafloor down to 1050 m (the planned setting depth for 13 3/8” casing). No shallow gas was encountered. Well 7220/7-1 was spudded with the semi-submersible installation Transocean Barents on 5 December 2011 and drilled to TD at 2230 m in the Late Triassic Fruholmen Formation. No significant problem was encountered in the operations. The well was drilled with seawater and hi-vis/bentonite sweeps down to 1060 m, with KCl/GEM/polymer mud from 1060 m to 1746 m, and with low sulphate KCl/GEM/polymer mud from 1746 m to TD.
    Well 7220/7-1 penetrated sediments ranging in age from Recent to Triassic. Below the glacio-marine Quaternary section at 485 m, an 831 m thick Tertiary sequence and a 424 m thick Cretaceous sequence were drilled to Top Jurassic (Fuglen Formation) at 1740 m. Top of target reservoir Stø Formation was encountered at 1781 m. The reservoir was gas bearing to the gas-oil-contact (GOC) at 1828 m, and oil bearing to the oil-water-contact (OWC) at 1956 m. Residual hydrocarbons was encountered below the OWC down to approximately 2121 m. No shows were recorded below this depth or above top reservoir. Results from the well thus indicate that flat-events seen on seismic at 1820 m and 1960 m, and 2105 m represent the GOC, the OWC, and a paleo-OWC, respectively. The Fruholmen Formation was penetrated at 2130 m, which was 7 m shallower than prognosed.
    Two short cores were cut in the overburden in the Kolmule and Kolje formations for field development purposes. A further seven cores were cut from 1785.5 m to 2120.5 m in the Stø, Nordmela and Tubåen Formations, covering the hydrocarbon zone and the water zone below, which is expected to be hydrocarbon-bearing up-flank on the structure. The core depths were ca 1 - 2 m deeper than the logger depths for all cores. Extensive wire line logging was performed. MDT fluid samples were taken at 1793 m (gas), 1837 m (oil), 1894 m (oil), 1927 m (oil), 1971 m (water), and 2063 m (water).
    The well was permanently abandoned on 24 January 2012 as an oil and 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]
    1070.00
    2231.00

  • 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
    3
    1785.5
    1813.2
    [m ]
    4
    1831.2
    1868.3
    [m ]
    5
    1868.3
    1922.4
    [m ]
    6
    1922.4
    1967.9
    [m ]
    7
    1969.0
    2024.4
    [m ]
    8
    2024.4
    2077.6
    [m ]
    9
    2077.6
    2121.7
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    317.1
    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
    1070.0
    [m]
    DC
    FUGRO
    1080.0
    [m]
    DC
    FUGRO
    1090.0
    [m]
    DC
    FUGRO
    1100.0
    [m]
    DC
    FUGRO
    1110.0
    [m]
    DC
    FUGRO
    1120.0
    [m]
    DC
    FUGRO
    1130.0
    [m]
    DC
    FUGRO
    1140.0
    [m]
    DC
    FUGRO
    1150.0
    [m]
    DC
    FUGRO
    1160.0
    [m]
    DC
    FUGRO
    1170.0
    [m]
    DC
    FUGRO
    1180.0
    [m]
    DC
    FUGRO
    1190.0
    [m]
    DC
    FUGRO
    1200.0
    [m]
    DC
    FUGRO
    1210.0
    [m]
    DC
    FUGRO
    1220.0
    [m]
    DC
    FUGRO
    1230.0
    [m]
    DC
    FUGRO
    1240.0
    [m]
    DC
    FUGRO
    1250.0
    [m]
    DC
    FUGRO
    1260.0
    [m]
    DC
    FUGRO
    1270.0
    [m]
    DC
    FUGRO
    1280.0
    [m]
    DC
    FUGRO
    1290.0
    [m]
    DC
    FUGRO
    1300.0
    [m]
    DC
    FUGRO
    1320.0
    [m]
    DC
    FUGRO
    1330.0
    [m]
    DC
    FUGRO
    1340.0
    [m]
    DC
    FUGRO
    1350.0
    [m]
    DC
    FUGRO
    1360.0
    [m]
    DC
    FUGRO
    1370.0
    [m]
    DC
    FUGRO
    1380.0
    [m]
    DC
    FUGRO
    1390.0
    [m]
    DC
    FUGRO
    1400.0
    [m]
    DC
    FUGRO
    1410.0
    [m]
    DC
    FUGRO
    1420.0
    [m]
    DC
    FUGRO
    1430.0
    [m]
    DC
    FUGRO
    1440.0
    [m]
    DC
    FUGRO
    1450.0
    [m]
    DC
    FUGRO
    1460.0
    [m]
    DC
    FUGRO
    1470.0
    [m]
    DC
    FUGRO
    1480.0
    [m]
    DC
    FUGRO
    1490.0
    [m]
    DC
    FUGRO
    1500.0
    [m]
    DC
    FUGRO
    1510.0
    [m]
    DC
    FUGRO
    1520.0
    [m]
    DC
    FUGRO
    1530.0
    [m]
    DC
    FUGRO
    1550.0
    [m]
    DC
    FUGRO
    1560.0
    [m]
    DC
    FUGRO
    1570.0
    [m]
    DC
    FUGRO
    1580.0
    [m]
    DC
    FUGRO
    1590.0
    [m]
    DC
    FUGRO
    1600.0
    [m]
    DC
    FUGRO
    1610.0
    [m]
    DC
    FUGRO
    1615.0
    [m]
    CC
    FUGRO
    1616.0
    [m]
    CC
    FUGRO
    1630.0
    [m]
    DC
    FUGRO
    1640.0
    [m]
    DC
    FUGRO
    1650.0
    [m]
    DC
    FUGRO
    1660.0
    [m]
    DC
    FUGRO
    1670.0
    [m]
    DC
    FUGRO
    1680.0
    [m]
    DC
    FUGRO
    1690.0
    [m]
    DC
    FUGRO
    1700.0
    [m]
    DC
    FUGRO
    1710.0
    [m]
    DC
    FUGRO
    1720.0
    [m]
    DC
    FUGRO
    1722.0
    [m]
    CC
    FUGRO
    1725.9
    [m]
    CC
    FUGRO
    1730.0
    [m]
    DC
    FUGRO
    1740.0
    [m]
    DC
    FUGRO
    1748.0
    [m]
    DC
    FUGRO
    1751.0
    [m]
    DC
    FUGRO
    1754.0
    [m]
    DC
    FUGRO
    1757.0
    [m]
    DC
    FUGRO
    1760.0
    [m]
    DC
    FUGRO
    1763.0
    [m]
    DC
    FUGRO
    1766.0
    [m]
    DC
    FUGRO
    1769.0
    [m]
    DC
    FUGRO
    1772.0
    [m]
    DC
    FUGRO
    1775.0
    [m]
    DC
    FUGRO
    1778.0
    [m]
    DC
    FUGRO
    1781.0
    [m]
    DC
    FUGRO
    1784.0
    [m]
    DC
    FUGRO
    1785.8
    [m]
    CC
    FUGRO
    1788.9
    [m]
    CC
    FUGRO
    1791.9
    [m]
    CC
    FUGRO
    1793.0
    [m]
    CC
    FUGRO
    1797.0
    [m]
    CC
    FUGRO
    1800.9
    [m]
    CC
    FUGRO
    1804.0
    [m]
    CC
    FUGRO
    1806.9
    [m]
    CC
    FUGRO
    1809.5
    [m]
    CC
    FUGRO
    1812.7
    [m]
    CC
    FUGRO
    1813.9
    [m]
    CC
    FUGRO
    1816.9
    [m]
    CC
    FUGRO
    1819.3
    [m]
    CC
    FUGRO
    1822.2
    [m]
    CC
    FUGRO
    1825.6
    [m]
    CC
    FUGRO
    1828.7
    [m]
    CC
    FUGRO
    1831.6
    [m]
    CC
    FUGRO
    1834.9
    [m]
    CC
    FUGRO
    1837.4
    [m]
    CC
    FUGRO
    1840.4
    [m]
    CC
    FUGRO
    1843.8
    [m]
    CC
    FUGRO
    1846.8
    [m]
    CC
    FUGRO
    1849.8
    [m]
    CC
    FUGRO
    1852.9
    [m]
    CC
    FUGRO
    1855.9
    [m]
    CC
    FUGRO
    1858.4
    [m]
    CC
    FUGRO
    1862.5
    [m]
    CC
    FUGRO
    1865.6
    [m]
    CC
    FUGRO
    1868.6
    [m]
    CC
    FUGRO
    1871.9
    [m]
    CC
    FUGRO
    1874.9
    [m]
    CC
    FUGRO
    1877.9
    [m]
    CC
    FUGRO
    1878.3
    [m]
    CC
    FUGRO
    1882.0
    [m]
    CC
    FUGRO
    1884.9
    [m]
    CC
    FUGRO
    1887.6
    [m]
    CC
    FUGRO
    1891.6
    [m]
    CC
    FUGRO
    1893.9
    [m]
    CC
    FUGRO
    1897.6
    [m]
    CC
    FUGRO
    1900.9
    [m]
    CC
    FUGRO
    1904.0
    [m]
    CC
    FUGRO
    1910.0
    [m]
    CC
    FUGRO
    1914.8
    [m]
    CC
    FUGRO
    1918.5
    [m]
    CC
    FUGRO
    1921.7
    [m]
    CC
    FUGRO
    1923.7
    [m]
    CC
    FUGRO
    1928.0
    [m]
    CC
    FUGRO
    1934.0
    [m]
    CC
    FUGRO
    1940.8
    [m]
    CC
    FUGRO
    1945.2
    [m]
    CC
    FUGRO
    1951.7
    [m]
    CC
    FUGRO
    1957.7
    [m]
    CC
    FUGRO
    1963.5
    [m]
    CC
    FUGRO
    1969.9
    [m]
    CC
    FUGRO
    1975.7
    [m]
    CC
    FUGRO
    1981.6
    [m]
    CC
    FUGRO
    1987.7
    [m]
    CC
    FUGRO
    1993.8
    [m]
    CC
    FUGRO
    1999.3
    [m]
    CC
    FUGRO
    2004.7
    [m]
    CC
    FUGRO
    2006.9
    [m]
    CC
    FUGRO
    2013.0
    [m]
    CC
    FUGRO
    2018.9
    [m]
    CC
    FUGRO
    2024.3
    [m]
    CC
    FUGRO
    2030.8
    [m]
    CC
    FUGRO
    2036.9
    [m]
    CC
    FUGRO
    2042.9
    [m]
    CC
    FUGRO
    2047.4
    [m]
    CC
    FUGRO
    2055.6
    [m]
    CC
    FUGRO
    2057.5
    [m]
    CC
    FUGRO
    2061.6
    [m]
    CC
    FUGRO
    2068.0
    [m]
    CC
    FUGRO
    2072.7
    [m]
    CC
    FUGRO
    2079.6
    [m]
    CC
    FUGRO
    2087.6
    [m]
    CC
    FUGRO
    2089.8
    [m]
    CC
    FUGRO
    2096.4
    [m]
    CC
    FUGRO
    2100.4
    [m]
    CC
    FUGRO
    2108.9
    [m]
    CC
    FUGRO
    2115.7
    [m]
    CC
    FUGRO
    2121.2
    [m]
    CC
    FUGRO
    2123.0
    [m]
    DC
    FUGRO
    2129.0
    [m]
    DC
    FUGRO
    2135.0
    [m]
    DC
    FUGRO
    2141.0
    [m]
    DC
    FUGRO
    2147.0
    [m]
    DC
    FUGRO
    2153.0
    [m]
    DC
    FUGRO
    2159.0
    [m]
    DC
    FUGRO
    2165.0
    [m]
    DC
    FUGRO
    2174.0
    [m]
    DC
    FUGRO
    2177.0
    [m]
    DC
    FUGRO
    2183.0
    [m]
    DC
    FUGRO
    2189.0
    [m]
    DC
    FUGRO
    2195.0
    [m]
    DC
    FUGRO
    2201.0
    [m]
    DC
    FUGRO
    2207.0
    [m]
    DC
    FUGRO
    2213.0
    [m]
    DC
    FUGRO
    2219.0
    [m]
    DC
    FUGRO
    2225.0
    [m]
    DC
    FUGRO
    2231.0
    [m]
    DC
    FUGRO

  • 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
    MDT
    1894.00
    0.00
    OIL
    YES
    MDT
    1793.00
    0.00
    OIL
    11.01.2012 - 00:00
    YES
    MDT
    1793.00
    0.00
    OIL
    11.01.2012 - 00:00
    NO

  • Lithostratigraphy

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    FMI ECS HNGS GR
    935
    1746
    MWD - GVR6 PERI TELE
    1746
    1784
    MWD - PENSCOPE TELE
    1784
    1969
    XPT HRLA PEX
    1747
    2076
    ZAIT IS MSIP PEX
    865
    1720

  • 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
    468.0
    36
    470.0
    0.00
    LOT
    SURF.COND.
    13 3/8
    1042.0
    17 1/2
    1065.0
    1.24
    LOT
    INTERM.
    9 5/8
    1747.0
    12 1/4
    1748.0
    1.87
    LOT
    OPEN HOLE
    2230.0
    8 1/2
    2230.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    1058
    1.15
    14.0
    KCl/Polymer/Glycol
    1119
    1.15
    13.0
    KCl/Polymer/Glycol
    1228
    1.16
    23.0
    KCl/Polymer/Glycol
    1380
    1.16
    15.0
    KCl/Polymer/Glycol
    1550
    1.39
    13.0
    Spud Mud
    1550
    1.35
    13.0
    Seawater
    1615
    1.16
    13.0
    KCl/Polymer/Glycol
    1622
    1.16
    17.0
    KCl/Polymer/Glycol
    1748
    1.16
    14.0
    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
    0.28