Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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16.07.2024 - 01:28
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7120/2-2

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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.
    7120/2-2
    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
    Well name
    Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    7120/2-2
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    NH8904 - 005 SP 470
    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.
    665-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,
    27.01.1991
    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.
    23.03.1991
    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.
    23.03.1993
    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 SHOWS
    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.
    NO
    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.
    336.5
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2794.0
    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).
    2794.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    12
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    87
    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.
    MIDDLE JURASSIC
    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.
    STØ FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    71° 50' 23.99'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    20° 36' 3.59'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7971348.28
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    486119.44
    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.
    1690
  • Wellbore history

    General
    Well 7120/2-2 was designed to test the Mesozoic rocks on a down-faulted position, south of the Loppa High. Well 7120/1-2 about 12.5 km to the southwest had tested minor amounts of oil in the Early Cretaceous. This was a new play concept on the Barents Shelf related to structural/stratigraphic combination traps as a result of wedge sedimentation in conjunction with the Kimmeridgian tectonic phase. The main objectives of the well were to test the prospectivity of the Early Cretaceous fan systems (wedge I and II) in an optimal position, and to test the prospectivity of the Middle Jurassic Stø Formation. The pore pressure was expected to be normal throughout the well. Shallow gas warnings were given for two levels down to 1437 m. A fault with displacement less than 10 m was seen at the planned well location at depth ca 565 m.
    Operations and results
    Wildcat well 7120/2-2 was spudded with the semi-submersible rig Polar Pioneer on 27 January 1991 and drilled to TD at 2800 m in Early Jurassic sandstones of the Stø Formation. The well was drilled with spud mud down to 800 m and with KCl polymer mud from 800 m to TD. No shallow gas intervals were penetrated. No major problems were experienced while drilling the hole.
    The first wedge, in the Kolmule Formation, was penetrated at 1712 m. The second wedge, expected to be sandstones of the Knurr Formation, was penetrated at 2125 m. Oil shows, mostly weak, were recorded from the top of this wedge and down to ca 2700 m. The strongest shows were recorded on a core from 2393 m to 2403 m. Geochemical analyses proved a ten metre claystone sequence with excellent source rock potential at 2120 m on top of the wedge; around 6% TOC and Hydrogen Index around 480 mg HC/g TOC. Vitrinite reflectance in the sequence is in the range 0.55 to 0.60 % Ro and Tmax around 434 deg C, corresponding to early oil window maturity. A second excellent source interval was penetrated in the Late Jurassic Hekkingen Formation at 2503 m. This sequence is 154 m thick and contain from 3 to 12% TOC with Hydrogen Index from 180 to 250 mg HC / g TOC. Vitrinite reflection was measured in the range 0.51 to 0.71 and Tmax in the range 442 deg C to 446 deg C, the latter indicating distinctly higher maturity in Hekkingen compared to Knurr. An RFT segregated sample was taken at 2501 m. It recovered water, oil and some gas. Geochemical analyses of the gas verified a light isotopic composition in all hydrocarbon components, indicating an early mature gas. The oil biomarkers indicated a maturity of the RFT oil corresponding to %Ro in the range 0.6 to 0.9. A total of six conventional cores were cut in the well: core 1 from 1895 m to 1923 m in the upper wedge/Kolmule Formation, core 2, 3, and 4 in the interval 2163 m to 2403 m in the lower wedge/Knurr Formation, core 5 from 2636 m to 2646 m in the Lower Hekkingen Formation, and core 6 from 2720 to 2724 m in the Stø Formation. A total of 120 sidewall cores were attempted and 97 were recovered.
    The well was permanently plugged and abandoned on 21 March 1991 as a dry hole with minor shows in Cretaceous and Jurassic siltstones and sandstones.
    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]
    810.00
    2799.30
  • 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
    1895.0
    1922.7
    [m ]
    2
    2163.0
    2163.5
    [m ]
    3
    2180.0
    2201.5
    [m ]
    4
    2393.0
    2400.9
    [m ]
    5
    2636.0
    2645.8
    [m ]
    6
    2720.0
    2723.5
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    70.9
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES
  • Core photos

    Core photos
    Core photo at depth: 1895-1900m
    Core photo at depth: 1900-1905m
    Core photo at depth: 1905-1910m
    Core photo at depth: 1910-1915m
    Core photo at depth: 1915-1920m
    1895-1900m
    1900-1905m
    1905-1910m
    1910-1915m
    1915-1920m
    Core photo at depth: 1920-1922m
    Core photo at depth: 2163-2164m
    Core photo at depth: 2180-2185m
    Core photo at depth: 2185-2190m
    Core photo at depth: 2190-2195m
    1920-1922m
    2163-2164m
    2180-2185m
    2185-2190m
    2190-2195m
    Core photo at depth: 2195-2200m
    Core photo at depth: 2200-2201m
    Core photo at depth: 2393-2398m
    Core photo at depth: 2398-2400m
    Core photo at depth: 2636-2641m
    2195-2200m
    2200-2201m
    2393-2398m
    2398-2400m
    2636-2641m
    Core photo at depth: 2641-2645m
    Core photo at depth: 2710-2723m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    2641-2645m
    2710-2723m
  • Palynological slides at the Norwegian Offshore Directorate

    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    810.0
    [m]
    DC
    HALIB
    830.0
    [m]
    DC
    HALIB
    850.0
    [m]
    DC
    HALIB
    870.0
    [m]
    DC
    HALIB
    890.0
    [m]
    DC
    HALIB
    910.0
    [m]
    DC
    HALIB
    930.0
    [m]
    DC
    HALIB
    960.0
    [m]
    DC
    HALIB
    970.0
    [m]
    DC
    HALIB
    990.0
    [m]
    DC
    HALIB
    1010.0
    [m]
    DC
    HALIB
    1030.0
    [m]
    DC
    HALIB
    1050.0
    [m]
    DC
    HALIB
    1070.0
    [m]
    DC
    HALIB
    1090.0
    [m]
    DC
    HALIB
    1110.0
    [m]
    DC
    HALIB
    1130.0
    [m]
    DC
    HALIB
    1150.0
    [m]
    DC
    HALIB
    1170.0
    [m]
    DC
    HALIB
    1190.0
    [m]
    DC
    HALIB
    1210.0
    [m]
    DC
    HALIB
    1230.0
    [m]
    DC
    HALIB
    1250.0
    [m]
    DC
    HALIB
    1270.0
    [m]
    DC
    HALIB
    1290.0
    [m]
    DC
    HALIB
    1310.0
    [m]
    DC
    HALIB
    1330.0
    [m]
    DC
    HALIB
    1350.0
    [m]
    DC
    HALIB
    1370.0
    [m]
    DC
    HALIB
    1390.0
    [m]
    DC
    HALIB
    1410.0
    [m]
    DC
    HALIB
    1430.0
    [m]
    DC
    HALIB
    1450.0
    [m]
    DC
    HALIB
    1470.0
    [m]
    DC
    HALIB
    1490.0
    [m]
    DC
    HALIB
    1510.0
    [m]
    DC
    HALIB
    1535.0
    [m]
    DC
    HALIB
    1560.0
    [m]
    DC
    HALIB
    1580.0
    [m]
    DC
    HALIB
    1600.0
    [m]
    DC
    HALIB
    1620.0
    [m]
    DC
    HALIB
    1640.0
    [m]
    DC
    HALIB
    1650.0
    [m]
    DC
    HALIB
    1660.0
    [m]
    DC
    HALIB
    1670.0
    [m]
    DC
    HALIB
    1680.0
    [m]
    DC
    HALIB
    1690.0
    [m]
    DC
    HALIB
    1700.0
    [m]
    DC
    HALIB
    1710.0
    [m]
    DC
    HALIB
    1720.0
    [m]
    DC
    HALIB
    1730.0
    [m]
    DC
    HALIB
    1740.0
    [m]
    DC
    HALIB
    1750.0
    [m]
    DC
    HALIB
    1760.0
    [m]
    DC
    HALIB
    1770.0
    [m]
    DC
    HALIB
    1780.0
    [m]
    DC
    HALIB
    1790.0
    [m]
    DC
    HALIB
    1805.0
    [m]
    DC
    HALIB
    1812.0
    [m]
    DC
    HALIB
    1822.0
    [m]
    DC
    HALIB
    1832.0
    [m]
    DC
    HALIB
    1835.0
    [m]
    SWC
    HYDRO
    1842.0
    [m]
    DC
    HALIB
    1852.0
    [m]
    DC
    HALIB
    1860.0
    [m]
    SWC
    HYDRO
    1862.0
    [m]
    DC
    HALIB
    1872.0
    [m]
    DC
    HALIB
    1882.0
    [m]
    DC
    HALIB
    1885.0
    [m]
    SWC
    HYDRO
    1890.0
    [m]
    DC
    HALIB
    1895.0
    [m]
    DC
    HALIB
    1895.1
    [m]
    C
    FUGRO
    1899.0
    [m]
    C
    HYDRO
    1900.0
    [m]
    DC
    HALIB
    1905.6
    [m]
    C
    FUGRO
    1908.0
    [m]
    C
    HYDRO
    1908.5
    [m]
    C
    FUGRO
    1910.0
    [m]
    DC
    HALIB
    1915.0
    [m]
    C
    HYDRO
    1917.8
    [m]
    C
    FUGRO
    1920.0
    [m]
    DC
    HALIB
    1922.7
    [m]
    C
    FUGRO
    1922.7
    [m]
    C
    HYDRO
    1930.0
    [m]
    SWC
    HYDRO
    1930.0
    [m]
    SWC
    HYDRO
    1930.0
    [m]
    DC
    HALIB
    1940.0
    [m]
    DC
    HALIB
    1940.0
    [m]
    SWC
    HYDRO
    1950.0
    [m]
    DC
    HALIB
    1955.0
    [m]
    SWC
    HYDRO
    1960.0
    [m]
    DC
    HALIB
    1970.0
    [m]
    DC
    HALIB
    1980.0
    [m]
    DC
    HALIB
    1980.0
    [m]
    SWC
    HYDRO
    1990.0
    [m]
    DC
    HALIB
    1997.0
    [m]
    DC
    HALIB
    2000.0
    [m]
    DC
    HALIB
    2000.0
    [m]
    SWC
    HYDRO
    2007.0
    [m]
    DC
    HALIB
    2012.0
    [m]
    DC
    HALIB
    2022.0
    [m]
    DC
    HALIB
    2025.0
    [m]
    SWC
    HYDRO
    2032.0
    [m]
    DC
    HALIB
    2042.0
    [m]
    DC
    HALIB
    2052.0
    [m]
    DC
    HALIB
    2055.0
    [m]
    SWC
    HYDRO
    2062.0
    [m]
    DC
    HALIB
    2072.0
    [m]
    DC
    HALIB
    2082.0
    [m]
    DC
    HALIB
    2092.0
    [m]
    DC
    HALIB
    2100.0
    [m]
    SWC
    HYDRO
    2102.0
    [m]
    DC
    HALIB
    2112.0
    [m]
    DC
    HALIB
    2115.0
    [m]
    SWC
    HYDRO
    2122.0
    [m]
    DC
    HALIB
    2125.0
    [m]
    DC
    HYDRO
    2127.0
    [m]
    DC
    HALIBURT
    2132.0
    [m]
    DC
    HALIBU
    2142.0
    [m]
    DC
    HALIBU
    2144.0
    [m]
    SWC
    HYDRO
    2145.0
    [m]
    SWC
    HYDRO
    2150.0
    [m]
    SWC
    HYDRO
    2152.0
    [m]
    DC
    HALIBURT
    2157.0
    [m]
    SWC
    HYDRO
    2162.0
    [m]
    DC
    HALIBURT
    2163.0
    [m]
    C
    FUGRO
    2172.0
    [m]
    DC
    HALIBURT
    2172.0
    [m]
    SWC
    HYDRO
    2173.0
    [m]
    SWC
    HYDRO
    2176.0
    [m]
    SWC
    HYDRO
    2181.9
    [m]
    C
    ICHRON
    2182.0
    [m]
    DC
    HALIBURT
    2182.3
    [m]
    C
    ICHRON
    2183.0
    [m]
    C
    HYDRO
    2184.9
    [m]
    C
    ICHRON
    2185.0
    [m]
    C
    HYDRO
    2186.3
    [m]
    C
    ICHRON
    2188.5
    [m]
    C
    ICHRON
    2191.7
    [m]
    C
    ICHRON
    2192.0
    [m]
    DC
    HALIBURT
    2193.0
    [m]
    C
    HYDRO
    2193.8
    [m]
    C
    ICHRON
    2194.3
    [m]
    C
    ICHRON
    2195.9
    [m]
    C
    ICHRON
    2196.5
    [m]
    C
    ICHRON
    2197.8
    [m]
    C
    ICHRON
    2198.0
    [m]
    C
    HYDRO
    2200.0
    [m]
    DC
    HALIBURT
    2201.5
    [m]
    C
    ICHRON
    2201.5
    [m]
    C
    HYDRO
    2205.0
    [m]
    SWC
    HYDRO
    2210.0
    [m]
    DC
    HALIBURT
    2212.0
    [m]
    SWC
    HYDRO
    2220.0
    [m]
    DC
    HALIBURT
    2222.0
    [m]
    SWC
    HYDRO
    2224.0
    [m]
    SWC
    HYDRO
    2227.0
    [m]
    DC
    HALIBURT
    2235.0
    [m]
    DC
    HALIBU
    2240.0
    [m]
    DC
    HALIBU
    2246.0
    [m]
    SWC
    HYDRO
    2250.0
    [m]
    DC
    HALIBURT
    2255.0
    [m]
    SWC
    HYDRO
    2260.0
    [m]
    DC
    HALIBURT
    2270.0
    [m]
    DC
    HALIBU
    2275.0
    [m]
    SWC
    HYDRO
    2280.0
    [m]
    DC
    HALIBURT
    2286.0
    [m]
    SWC
    HYDRO
    2290.0
    [m]
    DC
    HALIBURT
    2299.0
    [m]
    SWC
    HYDRO
    2300.0
    [m]
    DC
    HALIBURT
    2310.0
    [m]
    DC
    HALIBU
    2310.0
    [m]
    SWC
    HYDRO
    2316.0
    [m]
    SWC
    HYDRO
    2320.0
    [m]
    DC
    HALIBURT
    2327.0
    [m]
    SWC
    HYDRO
    2330.0
    [m]
    DC
    HALIBURT
    2332.0
    [m]
    SWC
    HYDRO
    2335.0
    [m]
    SWC
    HYDRO
    2340.0
    [m]
    DC
    HALIBURT
    2350.0
    [m]
    DC
    HALIBU
    2350.0
    [m]
    SWC
    HYDRO
    2357.0
    [m]
    SWC
    HYDRO
    2360.0
    [m]
    DC
    HALIBURT
    2370.0
    [m]
    DC
    HALIBU
    2380.0
    [m]
    DC
    HALIBU
    2380.0
    [m]
    SWC
    HYDRO
    2389.0
    [m]
    SWC
    HYDRO
    2390.0
    [m]
    DC
    HALIBURT
    2394.8
    [m]
    C
    ICHRON
    2395.0
    [m]
    C
    HYDRO
    2395.4
    [m]
    C
    ICHRON
    2396.0
    [m]
    C
    ICHRON
    2397.5
    [m]
    C
    ICHRON
    2398.0
    [m]
    C
    HYDRO
    2399.7
    [m]
    C
    ICHRON
    2400.0
    [m]
    DC
    HALIBURT
    2400.0
    [m]
    C
    HYDRO
    2400.3
    [m]
    C
    ICHRON
    2401.0
    [m]
    C
    HYDRO
    2410.0
    [m]
    SWC
    HYDRO
    2410.0
    [m]
    DC
    HALIBURT
    2420.0
    [m]
    SWC
    HYDRO
    2420.0
    [m]
    DC
    HALIBURT
    2428.0
    [m]
    SWC
    HYDRO
    2428.0
    [m]
    SWC
    HYDRO
    2430.0
    [m]
    DC
    HALIBURT
    2440.0
    [m]
    DC
    HALIBU
    2448.0
    [m]
    SWC
    HYDRO
    2450.0
    [m]
    DC
    HALIBURT
    2454.0
    [m]
    SWC
    HYDRO
    2460.0
    [m]
    DC
    HALIBURT
    2470.0
    [m]
    DC
    HALIBU
    2470.0
    [m]
    SWC
    HYDRO
    2480.0
    [m]
    DC
    HALIBURT
    2490.0
    [m]
    DC
    HALIBU
    2494.0
    [m]
    SWC
    HYDRO
    2500.0
    [m]
    DC
    HALIBURT
    2506.0
    [m]
    SWC
    HYDRO
    2510.0
    [m]
    DC
    HALIBURT
    2520.0
    [m]
    DC
    HALIBU
    2527.0
    [m]
    SWC
    HYDRO
    2530.0
    [m]
    DC
    HALIBURT
    2535.0
    [m]
    SWC
    HYDRO
    2540.0
    [m]
    SWC
    HYDRO
    2540.0
    [m]
    DC
    HALIBURT
    2550.0
    [m]
    DC
    HALIBU
    2560.0
    [m]
    DC
    HALIBU
    2565.0
    [m]
    SWC
    HYDRO
    2570.0
    [m]
    DC
    HALIBURT
    2585.0
    [m]
    DC
    HALIBU
    2587.0
    [m]
    DC
    HALIBU
    2597.0
    [m]
    DC
    HALIBU
    2605.0
    [m]
    SWC
    HYDRO
    2607.0
    [m]
    DC
    HALIBURT
    2615.0
    [m]
    DC
    HALIBU
    2625.0
    [m]
    SWC
    HYDRO
    2627.0
    [m]
    DC
    HALIBURT
    2637.0
    [m]
    DC
    HALIBU
    2638.0
    [m]
    C
    FUGRO
    2638.8
    [m]
    C
    FUGRO
    2638.8
    [m]
    C
    ICHRON
    2639.7
    [m]
    C
    ICHRON
    2644.8
    [m]
    C
    FUGRO
    2645.0
    [m]
    SWC
    HYDRO
    2647.0
    [m]
    DC
    HALIBURT
    2655.0
    [m]
    SWC
    HYDRO
    2657.0
    [m]
    DC
    HALIBURT
    2665.0
    [m]
    SWC
    HYDRO
    2667.0
    [m]
    DC
    HALIBURT
    2675.0
    [m]
    SWC
    HYDRO
    2677.0
    [m]
    DC
    HALIBURT
    2680.0
    [m]
    SWC
    HYDRO
    2687.0
    [m]
    DC
    HALIBURT
    2688.0
    [m]
    SWC
    HYDRO
    2697.0
    [m]
    DC
    HALIBURT
    2707.0
    [m]
    DC
    HALIBU
    2717.0
    [m]
    DC
    HALIBU
    2725.0
    [m]
    DC
    HALIBU
    2737.0
    [m]
    DC
    HALIBU
    2747.0
    [m]
    DC
    HALIBU
    2780.0
    [m]
    SWC
    HYDRO
    2788.0
    [m]
    SWC
    HYDRO
    2790.0
    [m]
    DC
    HALIBURT
    2796.0
    [m]
    SWC
    HYDRO
    2799.3
    [m]
    DC
    HALIBURT
  • Lithostratigraphy

  • Composite logs

    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.37
  • Geochemical information

    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    5.18
    pdf
    5.19
    pdf
    6.86
  • 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
    14.59
  • Logs

    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CST GR
    1810
    2783
    CST GR
    2326
    2796
    DIL LSS LDL CNL SP GR AMS
    786
    1268
    DIL SDT LDL CNL SP NGT AMS
    1785
    2796
    FMS GR AMS
    1785
    2798
    MSFL DLL GR
    2100
    2798
    MWD - GR RES DIR
    359
    1801
    MWD - GR RES DIR
    1974
    2795
    RFTA HP AMS
    2483
    2766
    RFTB HP AMS
    2134
    2693
    RFTB HP AMS
    2395
    2640
    RFTB HP AMS
    2395
    2501
    VSP
    1065
    2790
  • 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
    459.0
    36
    460.0
    0.00
    LOT
    INTERM.
    18 5/8
    785.0
    24
    788.0
    1.44
    LOT
    INTERM.
    13 3/8
    1785.0
    17 1/2
    1790.0
    1.29
    LOT
    OPEN HOLE
    2794.0
    12 1/4
    2794.0
    0.00
    LOT
  • Drilling mud

    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    360
    1.08
    WATER BASED
    29.01.1991
    380
    1.14
    16.0
    9.0
    WATER BASED
    20.03.1991
    421
    1.08
    WATER BASED
    29.01.1991
    445
    1.08
    WATER BASED
    30.01.1991
    459
    1.08
    WATER BASED
    30.01.1991
    459
    1.08
    WATER BASED
    31.01.1991
    583
    1.08
    WATER BASED
    01.02.1991
    720
    1.14
    9.0
    12.0
    WATER BASED
    21.03.1991
    800
    1.08
    WATER BASED
    05.02.1991
    800
    1.05
    18.0
    15.0
    WATER BASED
    05.02.1991
    800
    1.05
    18.0
    15.0
    WATER BASED
    08.02.1991
    800
    1.05
    18.0
    15.0
    WATER BASED
    08.02.1991
    800
    1.05
    18.0
    15.0
    WATER BASED
    12.02.1991
    853
    1.06
    9.0
    5.0
    WATER BASED
    12.02.1991
    1155
    1.08
    13.0
    8.0
    WATER BASED
    12.02.1991
    1350
    1.09
    13.0
    9.0
    WATER BASED
    12.02.1991
    1497
    1.09
    13.0
    7.0
    WATER BASED
    13.02.1991
    1544
    1.08
    13.0
    9.0
    WATER BASED
    14.02.1991
    1662
    1.10
    14.0
    10.0
    WATER BASED
    15.02.1991
    1685
    1.14
    16.0
    9.0
    WATER BASED
    20.03.1991
    1786
    1.12
    15.0
    11.0
    WATER BASED
    19.02.1991
    1805
    1.12
    15.0
    10.0
    WATER BASED
    19.02.1991
    1805
    1.12
    16.0
    11.0
    WATER BASED
    19.02.1991
    1805
    1.12
    15.0
    9.0
    WATER BASED
    19.02.1991
    1805
    1.14
    14.0
    10.0
    WATER BASED
    21.02.1991
    1805
    1.14
    15.0
    10.0
    WATER BASED
    26.02.1991
    1805
    1.14
    15.0
    1.0
    WATER BASED
    20.02.1991
    1805
    1.14
    15.0
    10.0
    WATER BASED
    22.02.1991
    1886
    1.14
    15.0
    8.0
    WATER BASED
    26.02.1991
    1895
    1.14
    15.0
    8.0
    WATER BASED
    26.02.1991
    1923
    1.14
    17.0
    8.0
    WATER BASED
    26.02.1991
    1933
    1.14
    17.0
    8.0
    WATER BASED
    27.02.1991
    2050
    1.14
    18.0
    10.0
    WATER BASED
    28.02.1991
    2162
    1.14
    16.0
    9.0
    WATER BASED
    01.03.1991
    2163
    1.14
    18.0
    9.0
    WATER BASED
    05.03.1991
    2180
    1.14
    18.0
    11.0
    WATER BASED
    05.03.1991
    2201
    1.14
    20.0
    9.0
    WATER BASED
    05.03.1991
    2205
    1.14
    19.0
    10.0
    WATER BASED
    05.03.1991
    2337
    1.14
    20.0
    10.0
    WATER BASED
    06.03.1991
    2402
    1.15
    18.0
    7.0
    WATER BASED
    07.03.1991
    2461
    1.15
    16.0
    9.0
    WATER BASED
    08.03.1991
    2568
    1.14
    19.0
    9.0
    WATER BASED
    11.03.1991
    2636
    1.14
    18.0
    10.0
    WATER BASED
    11.03.1991
    2646
    1.14
    17.0
    9.0
    WATER BASED
    11.03.1991
    2720
    1.15
    16.0
    8.0
    WATER BASED
    12.03.1991
    2726
    1.14
    15.0
    8.0
    WATER BASED
    13.03.1991
    2795
    1.14
    17.0
    9.0
    WATER BASED
    14.03.1991
    2800
    1.14
    16.0
    12.0
    WATER BASED
    18.03.1991
    2800
    1.14
    16.0
    10.0
    WATER BASED
    18.03.1991
    2800
    1.14
    15.0
    9.0
    WATER BASED
    18.03.1991
    2800
    1.14
    18.0
    9.0
    WATER BASED
    15.03.1991
    2800
    1.14
    18.0
    9.0
    WATER BASED
    15.03.1991
  • Thin sections at the Norwegian Offshore Directorate

    Thin sections at the Norwegian Offshore Directorate
    Depth
    Unit
    2163.00
    [m ]
    2181.25
    [m ]
    2184.25
    [m ]
    2190.75
    [m ]
    2393.25
    [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
    0.27