Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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22.11.2024 - 09:09
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7120/9-1

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  • General information
    General information
    Attribute Value
    Wellbore name
    Official name of wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    7120/9-1
    Type
    Wellbore type. Legal values: EXPLORATION, DEVELOPMENT, OTHER (see 'Purpose' for more information)
    EXPLORATION
    Purpose
    Final classification of the wellbore.

    Legal values for exploration wellbores:
    WILDCAT, APPRAISAL, WILDCAT-CCS, APPRAISAL-CCS.

    Legal values for development wellbores:
    OBSERVATION, PRODUCTION, INJECTION, INJECTION-CCS, OBSERVATION-CCS.

    Legal values for other wellbores:
    SOIL DRILLING (drilling in connection with track surveys and other subsurface surveys to investigate the soil conditions prior to placement of facilities),
    SHALLOW GAS (drilling to investigate shallow gas before the first 'real' drilling on the location),
    PILOT (drilling to investigate the geology and fluid connectors for location of the main wellbore),
    SCIENTIFIC (drilling according to Law of Scientific research and exploration),
    STRATIGRAPHIC (driling according to Law of Petroleum activities §2-1).
    WILDCAT
    Status
    Status for the wellbore. Legal values are:

    BLOWOUT: A blowout has occurred in the well.
    CLOSED: A development wellbore that has been closed in a shorter or longer periode. Also applies to development wellbores where drilling is completed, but production/injection has not yet been reported.
    DRILLING: The well is in the drilling phase - can be active drilling, logging, testing or plugging,
    JUNKED: The drilling operation has been terminated due to technical problems.
    P&A: Exploration: The well is plugged and abandoned, and can not be reentered for further use. Development wells: The production/injection from/to the well is stopped and the well is plugged. The wellhead is removed or else made unavailable for further well operations.
    PLUGGED: The wellbore has been plugged, but the upper parts of the wellbore can be re-used. A sidetrack might be drilled at a later stage.
    PRODUCING: It was produced from the wellbore at the time of the operators last monthly report to the Norwegian Offshore Directorate.
    INJECTING: It was injected to the wellbore at the time of the operators last monthly report to the Norwegian Offshore Directorate.
    PREDRILLED: The upper part of the well has been drilled, usually as part of a batch-drilling campaign covering several wellbores.
    RE-CLASS TO DEV: Exploration wellbore that is reclassified to a development wellbore.
    RE-CLASS TO TEST: Exploration wellbore that is reclassified to test production.
    SUSPENDED: The drilling operation in the wellbore has been temporarily stopped. The current plan is to continue drilling later on.
    P&A
    Factmaps in new window
    Main area
    Name of the area on the Norwegian Continental Shelf where the wellbore is located. Legal values: BARENTS SEA, NORWEGIAN SEA, NORTH SEA.
    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.
    7120/9-1
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    513 - 353 SP 1815
    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.
    338-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.
    64
    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,
    25.07.1982
    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.
    26.09.1982
    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.
    26.09.1984
    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.
    11.02.2005
    Purpose - planned
    Pre-drill purpose of the wellbore. Legal values for exploration wellbores: WILDCAT, APPRAISAL, WILDCAT-CCS, APPRAISAL-CCS. Example of legal values for development wellbores: OBSERVATION, PRODUCTION, INJECTION.
    WILDCAT
    Reentry
    Status whether the wellbore has been re-entered (YES) or not (NO). Re-entered wellbores are not included in the count when wellbores are presented in statistical overviews.
    NO
    Content
    For exploration wellbores, status of discovery.

    Legal values:
    DRY, SHOWS (trace amounts of hydrocarbons), GAS, GAS/CONDENSATE, OIL or OIL/GAS.
    SHOWS (GAS SHOWS, OIL SHOWS or OIL/GAS SHOWS) are detected as fluorescent cut (organic extract), petroleum odour, or visual stain on cuttings or cores, or as increased gas reading on the mud-loggers gas detection equipment.
    Legal values for WILDCAT-CCS and APPRAISAL-CCS: WATER

    For development wellbores, type of produced/injected fluid.
    Legal values:
    WATER, CUTTINGS, NOT AVAILABLE, OIL, GAS/CONDENSATE, OIL/GAS, CO2, GAS, WATER/GAS, NOT APPLICABLE.
    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 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.
    KAPP TOSCANA GP
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    23.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    320.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2300.0
    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).
    2300.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    3.2
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    73
    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° 29' 26.57'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    20° 56' 49.47'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7932342.99
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    498124.67
    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.
    82

  • Wellbore history
    General
    Well 7120/9-1 was drilled in the Hammerfest Basin. The primary objective of the well was to test sandstone reservoirs of Early to Middle Jurassic age at a location very close to the highest position of the prospective structure.
    The well was to be drilled into sediments of Triassic age to a prognosed depth of 2180 m +100/-130.
    Operations and results
    Exploration well 7120/9-1 was spudded with the semi-submersible installation Treasure Scout on 25July 1982 and drilled to TD at 2300 m in the Triassic Snadd Formation. The 36" section was drilled with a 17 1/2" bit followed by a 36" hole opener. Low penetration rates were encountered due to the over-compacted nature of the clay formation together with the presence of numerous erratic glacial boulders. The hole had to be reamed 3 times before the 30" casing was set. After that drilling proceeded without major problems. The 36" section was drilled with mud left from the previous well (7117/9-1). The 26" section down to 760 m was drilled with seawater and prehydrated bentonite. From 760 m to 1651 m the well was drilled with gypsum/"Milpolymer 302" mud, and from 1651 m to TD the well was drilled with "Milpolymer 302".
    The main reservoir was found hydrocarbon bearing from 1840.5 m (Top Stø Formation) down to the gas/water contact at 1904 m, eight meter into the Nordmela Formation. This interval consists of fine to medium, occasionally coarse sandstones with a few thin claystone stringers. RFT pressure recordings and sampling were performed over the interval. This gave a clear gas gradient of 0.084 psi/ft down to 1904 m with an underlying water gradient of 0.48 psi/ft. Weak to good shows were reported in sandstones in the interval from 1904 m in the lower part of the Early Jurassic and into the Triassic at TD. The water saturation in this interval ranged from 50-100% and based on log interpretation the hydrocarbons were assumed non-moveable.
    The pore pressure recordings and estimates in the well showed a normal pressure gradient down to ca. 1000 m, below which a slight pressure build up was estimated reaching a maximum recorded pressure of 1.14 r.d. at 1840.5 m. No further over pressured zones were noted. Seven cores were taken in the 12 1/4" section. Two segregated RFT samples were taken at 1842.5 m and 1900.5 m, both recovered dry gas.
    The well was permanently abandoned as gas discovery on 26 September 1982.
    Testing
    Two production tests were conducted. DST no. 1 (1935-1939 m) was opened for initial flow on a 15.9 mm. choke but did not flow. The well was perforated again and flowed for 10 minutes during DST no. 2. After a one-hour build up period, the well was again opened for flow without result. The well was re-perforated in DST no. 2A (1858-1864 m and 1869-1874 m) and flowed initially for 10 minutes. After a one-hour build up period, the well was flowed. During the main flow period an ice plug formed in the tubing. Three sets of separator samples were taken during this flow period. DST no 2A produced 291700 Sm3/day of gas with a gravity of 0.72 (air=l) and 10.9 Sm3/day of 53.5° API condensate through a 52/64" choke. The GOR was ca. 27000 Sm3/Sm3 and the CO2 content was 6.5%.

  • 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]
    410.00
    2300.00

  • 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
    1843.0
    1860.5
    [m ]
    2
    1861.0
    1879.2
    [m ]
    3
    1879.6
    1894.5
    [m ]
    4
    1894.5
    1912.2
    [m ]
    5
    1912.2
    1929.0
    [m ]
    6
    1929.7
    1947.4
    [m ]
    7
    1950.1
    1965.7
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    118.3
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 1843-1847m
    Core photo at depth: 1847-1851m
    Core photo at depth: 1851-1855m
    Core photo at depth: 1855-1859m
    Core photo at depth: 1859-1864m
    1843-1847m
    1847-1851m
    1851-1855m
    1855-1859m
    1859-1864m
    Core photo at depth: 1864-1868m
    Core photo at depth: 1868-1872m
    Core photo at depth: 1872-1877m
    Core photo at depth: 1877-1881m
    Core photo at depth: 1881-1885m
    1864-1868m
    1868-1872m
    1872-1877m
    1877-1881m
    1881-1885m
    Core photo at depth: 1885-1889m
    Core photo at depth: 1889-1893m
    Core photo at depth: 1893-1897m
    Core photo at depth: 1897-1902m
    Core photo at depth: 1902-1906m
    1885-1889m
    1889-1893m
    1893-1897m
    1897-1902m
    1902-1906m
    Core photo at depth: 1906-1910m
    Core photo at depth: 1910-1913m
    Core photo at depth: 1913-1917m
    Core photo at depth: 1917-1921m
    Core photo at depth: 1921-1926m
    1906-1910m
    1910-1913m
    1913-1917m
    1917-1921m
    1921-1926m
    Core photo at depth: 1926-1930m
    Core photo at depth: 1930-1934m
    Core photo at depth: 1934-1939m
    Core photo at depth: 1939-1943m
    Core photo at depth: 1943-1947m
    1926-1930m
    1930-1934m
    1934-1939m
    1939-1943m
    1943-1947m
    Core photo at depth: 1947-1951m
    Core photo at depth: 1951-1956m
    Core photo at depth: 1956-1960m
    Core photo at depth: 1960-1963m
    Core photo at depth: 1963-1965m
    1947-1951m
    1951-1956m
    1956-1960m
    1960-1963m
    1963-1965m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    772.0
    [m]
    SWC
    IKU
    798.0
    [m]
    SWC
    IKU
    846.0
    [m]
    SWC
    IKU
    868.0
    [m]
    SWC
    IKU
    894.0
    [m]
    SWC
    IKU
    921.0
    [m]
    SWC
    IKU
    940.5
    [m]
    SWC
    IKU
    947.0
    [m]
    SWC
    IKU
    947.9
    [m]
    SWC
    IKU
    953.0
    [m]
    SWC
    IKU
    955.0
    [m]
    DC
    957.5
    [m]
    SWC
    IKU
    965.0
    [m]
    DC
    971.0
    [m]
    SWC
    IKU
    985.0
    [m]
    DC
    989.9
    [m]
    SWC
    IKU
    995.1
    [m]
    SWC
    IKU
    1003.5
    [m]
    SWC
    IKU
    1010.0
    [m]
    SWC
    IKU
    1015.0
    [m]
    DC
    1019.0
    [m]
    SWC
    IKU
    1033.0
    [m]
    SWC
    IKU
    1035.0
    [m]
    DC
    1048.0
    [m]
    SWC
    IKU
    1057.0
    [m]
    SWC
    IKU
    1065.0
    [m]
    DC
    1066.0
    [m]
    SWC
    IKU
    1089.0
    [m]
    SWC
    IKU
    1110.0
    [m]
    DC
    1117.0
    [m]
    SWC
    IKU
    1135.0
    [m]
    DC
    1144.0
    [m]
    SWC
    IKU
    1165.0
    [m]
    DC
    1193.0
    [m]
    SWC
    IKU
    1195.0
    [m]
    DC
    1215.0
    [m]
    DC
    1219.0
    [m]
    SWC
    IKU
    1240.0
    [m]
    SWC
    IKU
    1240.0
    [m]
    DC
    1266.0
    [m]
    SWC
    IKU
    1280.0
    [m]
    DC
    1288.5
    [m]
    SWC
    IKU
    1310.0
    [m]
    DC
    1314.0
    [m]
    SWC
    IKU
    1345.0
    [m]
    DC
    1347.0
    [m]
    SWC
    IKU
    1357.0
    [m]
    SWC
    IKU
    1370.0
    [m]
    SWC
    IKU
    1370.0
    [m]
    DC
    1392.0
    [m]
    SWC
    IKU
    1395.0
    [m]
    DC
    1407.0
    [m]
    SWC
    IKU
    1430.0
    [m]
    DC
    1435.0
    [m]
    SWC
    IKU
    1460.0
    [m]
    DC
    1464.0
    [m]
    SWC
    IKU
    1491.0
    [m]
    SWC
    IKU
    1495.0
    [m]
    DC
    1516.5
    [m]
    SWC
    IKU
    1525.0
    [m]
    DC
    1540.0
    [m]
    DC
    1550.0
    [m]
    DC
    1560.0
    [m]
    DC
    1563.0
    [m]
    SWC
    IKU
    1575.0
    [m]
    DC
    1580.0
    [m]
    DC
    1585.0
    [m]
    SWC
    IKU
    1592.0
    [m]
    SWC
    IKU
    1597.5
    [m]
    SWC
    IKU
    1605.0
    [m]
    DC
    1616.0
    [m]
    SWC
    IKU
    1640.0
    [m]
    DC
    1640.0
    [m]
    DC
    1641.0
    [m]
    SWC
    IKU
    1650.0
    [m]
    SWC
    IKU
    1673.0
    [m]
    DC
    1681.5
    [m]
    SWC
    IKU
    1690.0
    [m]
    SWC
    IKU
    1695.0
    [m]
    DC
    1697.0
    [m]
    SWC
    IKU
    1707.5
    [m]
    SWC
    IKU
    1712.0
    [m]
    SWC
    IKU
    1722.5
    [m]
    SWC
    IKU
    1733.0
    [m]
    DC
    1735.0
    [m]
    SWC
    IKU
    1750.0
    [m]
    DC
    1751.5
    [m]
    SWC
    IKU
    1754.0
    [m]
    SWC
    IKU
    1758.0
    [m]
    SWC
    IKU
    1761.0
    [m]
    SWC
    IKU
    1765.0
    [m]
    SWC
    IKU
    1772.0
    [m]
    SWC
    IKU
    1773.0
    [m]
    DC
    1780.0
    [m]
    SWC
    IKU
    1783.0
    [m]
    DC
    1788.0
    [m]
    DC
    1792.0
    [m]
    SWC
    IKU
    1808.0
    [m]
    DC
    1813.0
    [m]
    DC
    1814.5
    [m]
    SWC
    IKU
    1817.0
    [m]
    SWC
    IKU
    1818.0
    [m]
    DC
    1820.0
    [m]
    DC
    1824.0
    [m]
    SWC
    IKU
    1825.0
    [m]
    DC
    1828.0
    [m]
    SWC
    IKU
    1830.0
    [m]
    DC
    1832.5
    [m]
    SWC
    IKU
    1837.0
    [m]
    SWC
    IKU
    1840.0
    [m]
    DC
    1843.0
    [m]
    DC
    1843.8
    [m]
    C
    IKU
    1847.6
    [m]
    C
    IKU
    1856.4
    [m]
    C
    IKU
    1860.4
    [m]
    C
    IKU
    1862.7
    [m]
    C
    IKU
    1864.2
    [m]
    C
    IKU
    1866.7
    [m]
    C
    IKU
    1866.9
    [m]
    C
    IKU
    1867.5
    [m]
    C
    IKU
    1868.0
    [m]
    DC
    1870.0
    [m]
    DC
    1870.9
    [m]
    C
    IKU
    1875.0
    [m]
    DC
    1876.9
    [m]
    C
    IKU
    1884.7
    [m]
    C
    IKU
    1885.0
    [m]
    DC
    1886.8
    [m]
    C
    IKU
    1888.8
    [m]
    C
    IKU
    1894.9
    [m]
    C
    IKU
    1895.0
    [m]
    DC
    1897.4
    [m]
    C
    IKU
    1898.0
    [m]
    DC
    1901.4
    [m]
    C
    IKU
    1903.3
    [m]
    C
    IKU
    1912.0
    [m]
    C
    IKU
    1915.5
    [m]
    C
    IKU
    1917.4
    [m]
    C
    IKU
    1919.6
    [m]
    C
    IKU
    1921.2
    [m]
    C
    IKU
    1923.0
    [m]
    C
    IKU
    1923.8
    [m]
    C
    IKU
    1924.7
    [m]
    C
    IKU
    1925.7
    [m]
    C
    IKU
    1926.4
    [m]
    C
    IKU
    1928.1
    [m]
    C
    IKU
    1928.8
    [m]
    C
    IKU
    1930.6
    [m]
    C
    IKU
    1936.7
    [m]
    C
    IKU
    1937.0
    [m]
    SWC
    IKU
    1937.4
    [m]
    C
    IKU
    1938.1
    [m]
    C
    IKU
    1939.7
    [m]
    C
    IKU
    1941.9
    [m]
    C
    IKU
    1949.9
    [m]
    C
    IKU
    1950.2
    [m]
    C
    IKU
    1952.2
    [m]
    C
    IKU
    1955.6
    [m]
    C
    IKU
    1956.7
    [m]
    C
    IKU
    1957.9
    [m]
    C
    IKU
    1958.4
    [m]
    C
    IKU
    1959.3
    [m]
    C
    IKU
    1960.6
    [m]
    C
    IKU
    1962.8
    [m]
    C
    IKU
    1965.0
    [m]
    C
    IKU
    2000.0
    [m]
    DC
    2010.0
    [m]
    DC
    2012.0
    [m]
    SWC
    IKU
    2028.0
    [m]
    DC
    2040.0
    [m]
    DC
    2048.5
    [m]
    SWC
    IKU
    2060.0
    [m]
    DC
    2063.0
    [m]
    SWC
    IKU
    2075.0
    [m]
    DC
    2079.0
    [m]
    SWC
    IKU
    2083.0
    [m]
    DC
    2088.0
    [m]
    DC
    2100.0
    [m]
    DC
    2110.0
    [m]
    SWC
    IKU
    2118.0
    [m]
    SWC
    IKU
    2128.0
    [m]
    SWC
    IKU
    2130.0
    [m]
    DC
    2136.0
    [m]
    SWC
    IKU
    2141.0
    [m]
    SWC
    IKU
    2147.0
    [m]
    SWC
    IKU
    2155.0
    [m]
    SWC
    IKU
    2155.0
    [m]
    DC
    2162.0
    [m]
    SWC
    IKU
    2170.0
    [m]
    SWC
    IKU
    2190.0
    [m]
    DC
    2192.0
    [m]
    SWC
    IKU
    2220.0
    [m]
    DC
    2221.0
    [m]
    SWC
    IKU
    2247.0
    [m]
    DC
    2276.0
    [m]
    SWC
    IKU
    2285.0
    [m]
    SWC
    IKU
    2285.0
    [m]
    DC
    2289.0
    [m]
    DC
    2289.0
    [m]
    SWC
    IKU
    2295.0
    [m]
    SWC
    IKU
    2297.0
    [m]
    DC

  • 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
    DST2A
    1869.00
    1874.00
    17.09.1982 - 00:00
    YES

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.42

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    2.23
    pdf
    3.97
    pdf
    3.14

  • 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
    9.12
    pdf
    2.81

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    1935
    1936
    0.0
    2.0
    1858
    1864
    20.6
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    2.0
    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
    2.0
    11
    291000
    0.764
    0.720
    26697

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL VDL
    440
    1646
    CDT
    1675
    1837
    CST
    772
    1089
    CST
    1117
    1650
    CST
    1937
    2295
    DLL MSFL GR CAL SP
    1650
    1966
    HDT
    744
    2295
    ISF LSS GR SP
    404
    1653
    ISF LSS GR SP
    1800
    2297
    ISF LSS GR SP MSFL CAL
    1651
    1965
    LDT CNL GR CAL
    390
    1966
    LDT CNL NGT GR CAL
    1935
    2297
    NGT
    1650
    2297
    RFT
    1840
    1943
    RFT
    1900
    1900
    RFT
    1900
    2226
    RFT
    1900
    1901
    RFT
    1935
    2270
    VELOCITY
    558
    2300

  • 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
    404.0
    36
    405.0
    0.00
    LOT
    SURF.COND.
    20
    744.0
    26
    760.0
    1.67
    LOT
    INTERM.
    13 3/8
    1651.0
    17 1/2
    1665.0
    1.80
    LOT
    INTERM.
    9 5/8
    2300.0
    12 1/4
    2300.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    766
    1.06
    seawater
    1216
    1.15
    32.0
    9.0
    seawater
    1665
    1.20
    50.0
    10.5
    seawater
    1821
    1.21
    41.0
    8.0
    seawater
    2059
    1.22
    46.0
    10.0
    seawater
    2285
    1.25
    50.0
    11.5
    seawater

  • 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
    0.27