Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
22.11.2024 - 09:09
Time of last synchronization with Norwegian Offshore Directorate's internal systems

7120/1-2

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.
    7120/1-2
    Type
    Wellbore type. Legal values: EXPLORATION, DEVELOPMENT, OTHER (see 'Purpose' for more information)
    EXPLORATION
    Purpose
    Final classification of the wellbore.

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

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

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

    BLOWOUT: A blowout has occurred in the well.
    CLOSED: A development wellbore that has been closed in a shorter or longer periode. Also applies to development wellbores where drilling is completed, but production/injection has not yet been reported.
    DRILLING: The well is in the drilling phase - can be active drilling, logging, testing or plugging,
    JUNKED: The drilling operation has been terminated due to technical problems.
    P&A: Exploration: The well is plugged and abandoned, and can not be reentered for further use. Development wells: The production/injection from/to the well is stopped and the well is plugged. The wellhead is removed or else made unavailable for further well operations.
    PLUGGED: The wellbore has been plugged, but the upper parts of the wellbore can be re-used. A sidetrack might be drilled at a later stage.
    PRODUCING: It was produced from the wellbore at the time of the operators last monthly report to the Norwegian Offshore Directorate.
    INJECTING: It was injected to the wellbore at the time of the operators last monthly report to the Norwegian Offshore Directorate.
    PREDRILLED: The upper part of the well has been drilled, usually as part of a batch-drilling campaign covering several wellbores.
    RE-CLASS TO DEV: Exploration wellbore that is reclassified to a development wellbore.
    RE-CLASS TO TEST: Exploration wellbore that is reclassified to test production.
    SUSPENDED: The drilling operation in the wellbore has been temporarily stopped. The current plan is to continue drilling later on.
    P&A
    Factmaps in new window
    Main area
    Name of the area on the Norwegian Continental Shelf where the wellbore is located. Legal values: BARENTS SEA, NORWEGIAN SEA, NORTH SEA.
    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.
    7120/1-2
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    86 - 107 / 7147 - 82 A
    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.
    A/S Norske Shell
    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.
    599-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.
    87
    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,
    01.01.1989
    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.
    28.03.1989
    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.
    28.03.1991
    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.
    18.05.2004
    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
    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.
    KNURR 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.
    LATE 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.
    HEKKINGEN 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.
    304.5
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2630.0
    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).
    2613.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    17.8
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    77
    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.
    71° 47' 29.04'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    20° 16' 42.98'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7966032.04
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    474839.56
    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.
    1366

  • Wellbore history
    General
    Block 7120/1 is situated on the southern margin of the Loppa High and is bisected by the east-west trending Southern Loppa High boundary fault, which separates the Loppa High from the Hammerfest Basin to the south. The main objective of well 7120/1-2 was two seismostratigraphically defined wedges (of inferred Aptian age) in a large fault-bound closure against the Loppa High. Additional objectives were provided by a lower wedge of inferred Hauterivian age and Early Jurassic/Late Triassic elastics truncated beneath the Base Cretaceous unconformity, both down dip from the structural culmination.
    Operations and results
    The well spudded with the semi-submersible installation Ross Rig on 1 January 1989 and drilled to a total depth of 2630 m in Late Triassic sediments of the Fruholmen Formation. No shallow gas was encountered at any depth. The rig had to be moved three times due to problems with boulders that increased the hole inclination too much. Rough weather conditions, with waves exceeding 16 m, delayed drilling with several days. The well was drilled with seawater and spud mud down to 617 m and with KCl /Polymer mud from 617 m to TD.
    Well 7120/1-2 penetrated two seismically defined "wedges" which contained three distinct clastic packages. The uppermost wedge (Wedge I from1585 m to1826 m) was dated as Early to Middle Albian in age, whilst the lower hydrocarbon-bearing wedge contains two units of latest Ryazanian / Early Valanginian (Wedge IIa from1878 m to 1984 m) and Early Volgian age (Wedge IIb from1984 m to 2138 m) respectively. These units had not previously been penetrated on the Barents Shelf.
    Oil shows (direct fluorescence) was recorded on cuttings and cores in several intervals below 1931 m. Based on DST, logs, cores and RFT pressure measurements it was concluded that an oil column in excess of 90 m was encountered in Wedge IIa. Hydrocarbon saturations were considered reliable and although averaging only 50 %, could be as high as 65 % in both the upper and lower reservoir intervals (corresponding to Production Tests 3A and 3B respectively). Reservoir properties in the hydrocarbon-bearing interval were in general very poor and the intercalation of thin sand-shale beds made it impossible to pick an oil-water contact with any confidence. All other interpreted hydrocarbons, with the exception of an isolated sand in the Hekkingen Formation, were considered to be immovable. A segregated RFT sample was recovered from 1888.5 m (within the Production Test 3A interval in the Lower Cretaceous reservoirs of Wedge IIa). Both sample chambers were opened on the rig and found to contain oil, water and gas. A total of 0.0012 m3 of 31 deg API (0.871 g/cm3) oil was recovered along with 0.074 m3 of gas. A second RFT sample was recovered from 2153.5 m (a two to five meter thick isolated sand in the Upper Jurassic Hekkingen Formation). The lower sampling chamber from this interval was opened on the rig; it contained 0.0023 m3 of 41°API (0.820 g/cm3) oil and 0.3706 m3 of gas. Attempts to recover RFT samples and pressures from the interval 2506 m to 2543 m failed due to tight Formation. Four conventional cores were cut. In addition, a 10 cm core was recovered from the junk basket tool run to retrieve lost bullets prior to drilling ahead at the 7" liner depth. Core 1 was cut from 1815 m to 1825 m in Wedge I, core 2 was cut from 1957 m to 1969 m in Wedge IIa, core 3 (from junk basket: black fissile claystone with strong smell of H2S) was retrieved from 2147 m in the Hekkingen Formation, core 4 was cut from 2581 m to 2583 m, and the fifth core was cut from 2583 m to 2585.5 m. Cores 4 and 5 were cut in the Fruholmen Formation, and both jammed of.
    The well was permanently abandoned on 28 March 1989 as an oil discovery
    Testing
    Two hydrocarbon production tests were planned for well 7120/1-2. The planned test intervals were 2506 m to 2543 m (Production Test #1 in the Fruholmen Formation) and 1879 m to 1896 m / 1944 m to1971 m (Production Test 2A / Test 2B in Wedge IIa). During Production Test 2, the tubing conveyed perforating guns parted from the bottom hole assembly and perforated the water-bearing sands below the proposed test interval. This incident led to a repeat of the test over the interval 1879 m to1971 m as Production Test 3. Test 1 gave no flow, but bottom hole samples and bottoms up contained minute traces of oil. Test 2 produced water, while the final, oil zone test in Wedge IIa (Test 3A and Test 3B) proved moveable oil. However the oil came very slowly with alternating gas and slugs of emulsified oil, and only after displacement of the original diesel cushion with Nitrogen.

  • 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]
    630.00
    2630.00

  • 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
    1815.0
    1825.0
    [m ]
    2
    1957.0
    1968.0
    [m ]
    3
    2581.0
    2582.0
    [m ]
    4
    2582.0
    2585.5
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    25.5
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 1815-1820m
    Core photo at depth: 1820-1825m
    Core photo at depth: 1957-1962m
    Core photo at depth: 1962-1967m
    Core photo at depth: 1967-1968m
    1815-1820m
    1820-1825m
    1957-1962m
    1962-1967m
    1967-1968m
    Core photo at depth: 2581-2585m
    Core photo at depth: 2581-2585m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    2581-2585m
    2581-2585m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    413.3
    [m]
    SWC
    469.3
    [m]
    SWC
    531.3
    [m]
    SWC
    595.3
    [m]
    SWC
    643.0
    [m]
    SWC
    680.0
    [m]
    SWC
    800.0
    [m]
    SWC
    870.0
    [m]
    SWC
    980.0
    [m]
    SWC
    1020.0
    [m]
    SWC
    1065.0
    [m]
    SWC
    1145.0
    [m]
    SWC
    1160.0
    [m]
    SWC
    1420.0
    [m]
    SWC
    1460.0
    [m]
    SWC
    1500.0
    [m]
    SWC
    1558.0
    [m]
    DC
    1559.5
    [m]
    SWC
    RRI
    1563.5
    [m]
    SWC
    RRI
    1566.1
    [m]
    SWC
    1576.0
    [m]
    DC
    1584.9
    [m]
    SWC
    RRI
    1589.5
    [m]
    SWC
    1593.5
    [m]
    SWC
    RRI
    1594.0
    [m]
    DC
    1601.1
    [m]
    SWC
    1621.0
    [m]
    DC
    1625.1
    [m]
    SWC
    1643.0
    [m]
    DC
    1651.1
    [m]
    SWC
    1658.0
    [m]
    SWC
    RRI
    1677.0
    [m]
    SWC
    1682.0
    [m]
    DC
    1688.0
    [m]
    DC
    RRI
    1703.0
    [m]
    DC
    RRI
    1718.0
    [m]
    DC
    RRI
    1724.0
    [m]
    DC
    1748.0
    [m]
    DC
    RRI
    1754.0
    [m]
    DC
    1778.0
    [m]
    DC
    RRI
    1784.1
    [m]
    SWC
    1799.0
    [m]
    DC
    1808.0
    [m]
    DC
    RRI
    1808.0
    [m]
    SWC
    1811.0
    [m]
    DC
    1816.4
    [m]
    C
    1817.0
    [m]
    C
    RRI
    1817.4
    [m]
    C
    1817.5
    [m]
    C
    RRI
    1818.4
    [m]
    C
    1819.3
    [m]
    C
    FUGRO
    1819.4
    [m]
    C
    RRI
    1820.0
    [m]
    C
    RRI
    1820.1
    [m]
    C
    RRI
    1820.1
    [m]
    C
    1820.4
    [m]
    C
    1822.4
    [m]
    C
    1822.6
    [m]
    C
    1822.6
    [m]
    C
    FUGRO
    1830.5
    [m]
    SWC
    RRI
    1835.0
    [m]
    DC
    1838.0
    [m]
    SWC
    RRI
    1838.0
    [m]
    SWC
    1844.0
    [m]
    DC
    1853.0
    [m]
    DC
    1856.5
    [m]
    SWC
    RRI
    1862.0
    [m]
    DC
    1863.1
    [m]
    SWC
    1863.1
    [m]
    SWC
    RRI
    1868.0
    [m]
    SWC
    RRI
    1871.0
    [m]
    DC
    1880.0
    [m]
    DC
    1883.5
    [m]
    SWC
    1883.5
    [m]
    DC
    RRI
    1889.0
    [m]
    DC
    1898.0
    [m]
    SWC
    RRI
    1901.0
    [m]
    DC
    1904.0
    [m]
    DC
    RRI
    1905.1
    [m]
    SWC
    1910.0
    [m]
    DC
    1913.0
    [m]
    DC
    RRI
    1919.0
    [m]
    DC
    1922.0
    [m]
    DC
    RRI
    1928.0
    [m]
    DC
    RRI
    1928.5
    [m]
    SWC
    1931.0
    [m]
    DC
    1937.0
    [m]
    DC
    RRI
    1940.0
    [m]
    DC
    1943.0
    [m]
    DC
    RRI
    1946.0
    [m]
    DC
    RRI
    1949.0
    [m]
    DC
    1953.6
    [m]
    SWC
    1955.0
    [m]
    DC
    1957.0
    [m]
    C
    1957.0
    [m]
    C
    RRI
    1957.7
    [m]
    C
    FUGRO
    1958.3
    [m]
    C
    1959.2
    [m]
    C
    RRI
    1959.2
    [m]
    C
    ICHRON
    1959.2
    [m]
    C
    FUGRO
    1959.4
    [m]
    C
    ICHRON
    1960.0
    [m]
    C
    ICHRON
    1960.1
    [m]
    C
    ICHRON
    1960.9
    [m]
    C
    RRI
    1960.9
    [m]
    C
    ICHRON
    1961.2
    [m]
    C
    ICHRON
    1961.5
    [m]
    C
    ICHRON
    1962.4
    [m]
    C
    ICHRON
    1963.0
    [m]
    C
    ICHRON
    1963.5
    [m]
    C
    ICHRON
    1963.9
    [m]
    C
    ICHRON
    1964.1
    [m]
    C
    RRI
    1964.2
    [m]
    C
    ICHRON
    1964.5
    [m]
    C
    1964.6
    [m]
    DC
    1964.9
    [m]
    C
    ICHRON
    1965.2
    [m]
    C
    RRI
    1965.2
    [m]
    C
    1965.5
    [m]
    C
    ICHRON
    1965.9
    [m]
    C
    ICHRON
    1966.0
    [m]
    C
    FUGRO
    1966.1
    [m]
    C
    ICHRON
    1966.4
    [m]
    C
    ICHRON
    1966.5
    [m]
    C
    1966.8
    [m]
    C
    FUGRO
    1966.8
    [m]
    C
    ICHRON
    1967.3
    [m]
    C
    ICHRON
    1967.3
    [m]
    C
    1967.5
    [m]
    C
    1967.8
    [m]
    C
    RRI
    1967.8
    [m]
    C
    ICHRON
    1971.5
    [m]
    SWC
    RRI
    1971.5
    [m]
    SWC
    1973.0
    [m]
    DC
    1975.2
    [m]
    SWC
    1977.5
    [m]
    SWC
    1980.0
    [m]
    SWC
    RRI
    1980.0
    [m]
    SWC
    1981.5
    [m]
    SWC
    RRI
    1981.5
    [m]
    SWC
    1982.0
    [m]
    DC
    1988.0
    [m]
    DC
    RRI
    1991.0
    [m]
    DC
    1992.3
    [m]
    SWC
    2000.0
    [m]
    DC
    RRI
    2000.0
    [m]
    DC
    2009.0
    [m]
    DC
    2009.0
    [m]
    DC
    RRI
    2016.6
    [m]
    SWC
    2018.0
    [m]
    DC
    RRI
    2018.0
    [m]
    DC
    2030.0
    [m]
    DC
    2030.0
    [m]
    DC
    RRI
    2042.0
    [m]
    DC
    2048.0
    [m]
    DC
    RRI
    2051.0
    [m]
    DC
    2060.0
    [m]
    DC
    2063.0
    [m]
    SWC
    2067.1
    [m]
    SWC
    RRI
    2067.1
    [m]
    SWC
    2069.0
    [m]
    DC
    2078.0
    [m]
    DC
    RRI
    2081.0
    [m]
    DC
    2090.0
    [m]
    DC
    2097.1
    [m]
    SWC
    2099.0
    [m]
    DC
    2108.0
    [m]
    DC
    RRI
    2110.1
    [m]
    SWC
    2111.0
    [m]
    DC
    RRI
    2111.0
    [m]
    DC
    2114.0
    [m]
    DC
    RRI
    2120.0
    [m]
    DC
    2129.0
    [m]
    DC
    2130.5
    [m]
    SWC
    2132.0
    [m]
    DC
    RRI
    2135.0
    [m]
    DC
    RRI
    2136.4
    [m]
    SWC
    2138.0
    [m]
    DC
    RRI
    2141.0
    [m]
    DC
    RRI
    2141.0
    [m]
    DC
    2147.0
    [m]
    DC
    2147.0
    [m]
    DC
    RRI
    2150.0
    [m]
    C
    STATOIL
    2150.0
    [m]
    DC
    2150.0
    [m]
    C
    RRI
    2150.0
    [m]
    C
    2156.0
    [m]
    SWC
    2156.0
    [m]
    SWC
    RRI
    2160.0
    [m]
    SWC
    RRI
    2165.0
    [m]
    DC
    2170.0
    [m]
    SWC
    2170.0
    [m]
    SWC
    RRI
    2180.0
    [m]
    SWC
    RRI
    2180.0
    [m]
    SWC
    2189.0
    [m]
    DC
    2195.0
    [m]
    SWC
    2198.0
    [m]
    DC
    2198.0
    [m]
    DC
    RRI
    2207.0
    [m]
    DC
    RRI
    2210.0
    [m]
    SWC
    2213.0
    [m]
    DC
    2219.0
    [m]
    DC
    2219.0
    [m]
    DC
    RRI
    2228.0
    [m]
    DC
    RRI
    2234.0
    [m]
    DC
    2243.0
    [m]
    DC
    RRI
    2244.0
    [m]
    SWC
    2246.0
    [m]
    DC
    2249.0
    [m]
    DC
    RRI
    2249.0
    [m]
    DC
    2258.0
    [m]
    DC
    RRI
    2270.0
    [m]
    DC
    2285.0
    [m]
    DC
    2285.0
    [m]
    DC
    RRI
    2357.0
    [m]
    DC
    2368.5
    [m]
    SWC
    2372.0
    [m]
    DC
    2384.0
    [m]
    DC
    2390.0
    [m]
    SWC
    2415.0
    [m]
    SWC
    2425.0
    [m]
    SWC
    2432.0
    [m]
    DC
    2448.0
    [m]
    SWC
    2450.0
    [m]
    DC
    2460.0
    [m]
    SWC
    2469.0
    [m]
    SWC
    2474.0
    [m]
    DC
    2507.0
    [m]
    DC
    2509.5
    [m]
    SWC
    2526.5
    [m]
    SWC
    2531.0
    [m]
    DC
    2555.0
    [m]
    DC
    2561.0
    [m]
    SWC
    2573.0
    [m]
    DC
    2582.6
    [m]
    C
    2584.5
    [m]
    C
    2585.4
    [m]
    C
    2597.0
    [m]
    DC
    2612.5
    [m]
    SWC
    2626.0
    [m]
    SWC

  • 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
    TEST3A
    1879.00
    1971.00
    21.03.1989 - 10:30
    YES
    DST
    1888.00
    1896.00
    21.03.1989 - 00:00
    YES
    DST
    DST3B
    1944.00
    1971.00
    22.03.1989 - 00:00
    YES

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.47

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    3.20

  • 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
    42.89

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    2.0
    1879
    1971
    12.7
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    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]
    2.0
    150
    0.673

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL VDL
    1164
    1546
    CBL VDL
    1440
    2145
    CHKSHT
    415
    2135
    CST
    414
    604
    CST
    623
    1537
    CST
    643
    1537
    CST
    1560
    2136
    CST
    1972
    2145
    CST
    2164
    2622
    CST
    2460
    2578
    DIL BHC
    402
    616
    DIL BHC
    610
    1550
    DIL BHC
    1546
    2144
    DIL BHC
    2145
    2561
    DIL BHC
    2477
    2628
    DIL MSFL
    2145
    2630
    DLL MSFL
    1546
    2137
    LDL CNL AMS
    610
    1552
    LDL CNL CAL
    402
    615
    LDL CNL NGS
    1546
    2144
    LDL CNL NGS
    2450
    2629
    LDL CNL NGT
    2144
    2564
    MWD
    342
    2140
    RFT
    2153
    2541
    RFT
    2508
    2578
    SHDT
    2145
    2630
    SHDT CAL
    1545
    2141
    VSP
    700
    2584

  • 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
    401.0
    36
    0.0
    0.00
    LOT
    INTERM.
    20
    607.0
    26
    622.0
    1.37
    LOT
    INTERM.
    9 5/8
    1544.0
    12 1/2
    1564.0
    1.27
    LOT
    LINER
    7
    2144.0
    8 1/2
    2151.0
    1.34
    LOT
    LINER
    4 1/2
    2630.0
    5 7/8
    2630.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    366
    1.04
    WATER BASED
    04.01.1989
    673
    1.02
    15.0
    20.0
    WATER BASED
    16.01.1989
    827
    1.20
    19.0
    24.0
    WATER BASED
    16.01.1989
    880
    1.20
    19.0
    24.0
    WATER BASED
    16.01.1989
    1100
    1.02
    17.0
    20.0
    WATER BASED
    17.01.1989
    1290
    1.20
    17.0
    19.0
    WATER BASED
    17.01.1989
    1500
    1.20
    20.0
    28.0
    WATER BASED
    19.01.1989
    1500
    1.20
    20.0
    28.0
    WATER BASED
    20.01.1989
    1500
    1.20
    20.0
    28.0
    WATER BASED
    25.01.1989
    1500
    1.20
    22.0
    34.0
    WATER BASED
    19.01.1989
    1600
    1.20
    21.0
    28.0
    WATER BASED
    25.01.1989
    1670
    1.20
    21.0
    20.0
    WATER BASED
    26.01.1989
    1740
    1.20
    26.0
    21.0
    WATER BASED
    26.01.1989
    1781
    1.20
    24.0
    21.0
    WATER BASED
    27.01.1989
    1781
    1.20
    24.0
    21.0
    WATER BASED
    30.01.1989
    1830
    1.18
    20.0
    21.0
    WATER BASED
    30.01.1989
    1850
    1.20
    WATER BASED
    20.03.1989
    1850
    1.20
    WATER BASED
    22.03.1989
    1850
    1.20
    WATER BASED
    28.03.1989
    1850
    1.20
    WATER BASED
    16.03.1989
    1887
    1.20
    22.0
    23.0
    WATER BASED
    31.01.1989
    1934
    1.20
    21.0
    23.0
    WATER BASED
    01.02.1989
    1950
    1.20
    22.0
    20.0
    WATER BASED
    03.02.1989
    1950
    1.20
    22.0
    20.0
    WATER BASED
    02.02.1989
    1990
    1.02
    WATER BASED
    22.03.1989
    2040
    1.18
    22.0
    22.0
    WATER BASED
    06.02.1989
    2050
    1.03
    WATER BASED
    13.03.1989
    2050
    1.03
    WATER BASED
    14.03.1989
    2050
    1.03
    WATER BASED
    15.03.1989
    2101
    1.18
    22.0
    22.0
    WATER BASED
    06.02.1989
    2140
    1.18
    20.0
    23.0
    WATER BASED
    08.02.1989
    2140
    1.18
    20.0
    23.0
    WATER BASED
    09.02.1989
    2140
    1.18
    20.0
    23.0
    WATER BASED
    13.02.1989
    2159
    1.20
    20.0
    21.0
    WATER BASED
    17.02.1989
    2160
    1.20
    20.0
    21.0
    WATER BASED
    20.02.1989
    2258
    1.20
    21.0
    23.0
    WATER BASED
    20.02.1989
    2384
    1.20
    21.0
    23.0
    WATER BASED
    20.02.1989
    2384
    1.20
    21.0
    23.0
    WATER BASED
    21.02.1989
    2456
    1.20
    21.0
    22.0
    WATER BASED
    22.02.1989
    2494
    1.20
    21.0
    22.0
    WATER BASED
    24.02.1989
    2550
    1.20
    21.0
    22.0
    WATER BASED
    27.02.1989
    2564
    1.20
    21.0
    22.0
    WATER BASED
    28.02.1989
    2581
    1.20
    21.0
    22.0
    WATER BASED
    28.02.1989
    2585
    1.20
    21.0
    22.0
    WATER BASED
    02.03.1989
    2585
    1.20
    21.0
    22.0
    WATER BASED
    28.02.1989
    2600
    1.03
    WATER BASED
    10.03.1989
    2600
    1.03
    WATER BASED
    07.03.1989
    2600
    1.03
    WATER BASED
    09.03.1989
    2600
    1.03
    WATER BASED
    13.03.1989
    2630
    1.03
    WATER BASED
    07.03.1989
    2630
    1.20
    21.0
    20.0
    WATER BASED
    03.03.1989
    2630
    1.20
    21.0
    20.0
    WATER BASED
    06.03.1989

  • Thin sections at the Norwegian Offshore Directorate
    Thin sections at the Norwegian Offshore Directorate
    Depth
    Unit
    1816.15
    [m ]
    1817.32
    [m ]
    1961.72
    [m ]
    1962.73
    [m ]
    2581.80
    [m ]
    2583.48
    [m ]

  • 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