Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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27.11.2024 - 01:27
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7120/8-2

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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.
    7120/8-2
    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).
    APPRAISAL
    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.
    7120/8-2
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    513 - 125 SP 2270
    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.
    Den norske stats oljeselskap a.s
    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.
    324-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.
    106
    Entered date
    The date when he wellbore was spudded. For sidetracks: The date when new formation was drilled by kicking off from the mother-wellbore,
    15.04.1982
    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.
    29.07.1982
    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.
    29.07.1984
    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.
    NO
    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.
    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
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    25.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    245.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2590.0
    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).
    2590.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    1.5
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    91
    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° 20' 15.72'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    20° 27' 57.61'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7915359.17
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    480927.89
    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.
    50

  • Wellbore history
    General
    The 7120/8-2 well was drilled on the Alpha-South structure in the Western part of the Hammerfest Basin. The first well in the block, well 7120/8-1, was drilled on the Alpha North closure in 1981, north of the major east - west fault splitting the two closures/structures. This well found gas-bearing sandstones in the Middle to Early Jurassic. The primary objective of well 7120/8-2 was to test possible hydrocarbon accumulations in sandstones of Middle to Early Jurassic age (Stø Formation) in the Alpha-South structure.
    Operations and results
    Well 7120/8-2 was spudded with the semi-submersible installation Neptuno Nordraug on 15 April 1982 and drilled to TD at 2590 m in Late Triassic sediments (Fruholmen Formation). The drilling of the 36" and 26" hole went forth without any problems. After this several problems occurred and 78 days were used to reach TD, 29 days more than programmed. The main hang-ups were: broken 20" csg, partly collapsed 13-3/8" csg, pulled BOP stack, roller system, and stucked stabilizer at 2156 m. The well was drilled with gel/spud mud down to 333 m, with gel/seawater from 333 m to 752 m, and with gel/lignosulphonate/seawater from 752 m to TD.
    Hydrocarbon accumulations were discovered in sandstone sequences between 2081-2161 m in the Stø Formaton. The reservoir sandstones showed good to excellent reservoir properties. Gas composition from the DST was almost identical to the gas composition of the DSTs performed in the 7120/8-1 well. This was also indicated by gas gradients established from the RFT pressure points taken in the two wells. RFT pressure points from the two wells also indicated that the water zone most likely is in communication. Organic geochemical analyses show TOC in the range 0.7 % to 2.8 % TOC in mudstones from the Early Cretaceous. The kerogen in these samples are Type IV / III with a poor potential, increasing to fair at the base, for gas. Olive black claystones of the Late Jurassic Hekkingen Formation has TOC from 2 % to 12 % with Type III kerogen on top grading to Type II at the base. With a large terrestrial input these source rocks have rich potential for gas, condensate and waxy crude oil. The Jurassic and Late Triassic sequences below the Hekkingen and Fuglen Formations are mainly sandstones interbedded with shale, and in the Early Jurassic and Late Triassic also coal seams appear. The shale interbeds here are classified as poor sources for gas (Type III), while the coals have excellent hydrocarbon potential and may be oil-prone. However, theses shales and coals do not constitute a significant volume of source rock in the well position, compared to the Hekkingen Formation. The maturity parameters show an immature well down to ca 2000 m where vitrinite reflection reaches 0.5 %Ro. From here the maturity increases to early oil window/peak oil window at TD, however the coals penetrated by the well are probably all immature in well position. Analyses of shows and a DST condensate from the Early Jurassic sandstones indicate a common source for the shows and the DST condensate. This source is most probably the Hekkingen Formation, but deeper coal seams cannot be excluded as a possibility.
    Eight cores were cut in succession from 2085 m in the Stø Formation to 2218 m, 28 meters into the Nordmela Formation. Two RFT samples were taken: one at 2083 m (gas, mud filtrate, formation water) and one at 2150.5 m (mud filtrate, formation water, small volume of gas).
    The well was permanently abandoned as a gas appraisal on 29 July 1982.
    Testing
    One DST was carried out in the interval from 2092-2097 m in the Stø Formation reservoir. The test flowed gas with a small amount of condensate. Condensate density was 0.778 g/cm3 and gas gravity was 0.679 (air = 1) with 4-5% CO2. No H2S was detected. Sand production was not observed and water production was limited to mud filtrate and water associated with the gas. The well was initially flowed for 840 min. before being shut in for 1350 min. The well was then opened for a multi -rate flow, which lasted 900 min. before being shut in for 300 min.

  • 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]
    330.00
    2588.00

  • 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
    2085.0
    2101.4
    [m ]
    2
    2101.4
    2120.0
    [m ]
    3
    2120.0
    2138.0
    [m ]
    4
    2138.0
    2153.6
    [m ]
    5
    2153.6
    2172.0
    [m ]
    6
    2172.0
    2185.6
    [m ]
    7
    2185.5
    2200.3
    [m ]
    8
    2201.0
    2218.5
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    132.9
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 2085-2090m
    Core photo at depth: 2090-2095m
    Core photo at depth: 2095-2100m
    Core photo at depth: 2100-2101m
    Core photo at depth: 2101-2106m
    2085-2090m
    2090-2095m
    2095-2100m
    2100-2101m
    2101-2106m
    Core photo at depth: 2106-2111m
    Core photo at depth: 2101-2106m
    Core photo at depth: 2111-2116m
    Core photo at depth: 2116-2120m
    Core photo at depth: 2120-2125m
    2106-2111m
    2101-2106m
    2111-2116m
    2116-2120m
    2120-2125m
    Core photo at depth: 2125-2130m
    Core photo at depth: 2130-2135m
    Core photo at depth: 2135-2138m
    Core photo at depth: 2138-2143m
    Core photo at depth: 2148-2153m
    2125-2130m
    2130-2135m
    2135-2138m
    2138-2143m
    2148-2153m
    Core photo at depth: 2153-2154m
    Core photo at depth: 2153-2158m
    Core photo at depth: 2158-2163m
    Core photo at depth: 2163-2168m
    Core photo at depth: 2168-2172m
    2153-2154m
    2153-2158m
    2158-2163m
    2163-2168m
    2168-2172m
    Core photo at depth: 2172-2177m
    Core photo at depth: 2182-2185m
    Core photo at depth: 2185-2190m
    Core photo at depth: 2190-2195m
    Core photo at depth: 2195-2000m
    2172-2177m
    2182-2185m
    2185-2190m
    2190-2195m
    2195-2000m
    Core photo at depth: 2201-2206m
    Core photo at depth: 2206-2211m
    Core photo at depth: 2211-2216m
    Core photo at depth: 2216-2218m
    Core photo at depth:  
    2201-2206m
    2206-2211m
    2211-2216m
    2216-2218m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    330.0
    [m]
    DC
    PAS
    350.0
    [m]
    DC
    PAS
    370.0
    [m]
    DC
    PAS
    390.0
    [m]
    DC
    PAS
    410.0
    [m]
    DC
    PAS
    430.0
    [m]
    DC
    PAS
    450.0
    [m]
    DC
    PAS
    470.0
    [m]
    DC
    PAS
    490.0
    [m]
    DC
    PAS
    510.0
    [m]
    DC
    PAS
    530.0
    [m]
    DC
    PAS
    550.0
    [m]
    DC
    PAS
    570.0
    [m]
    DC
    PAS
    590.0
    [m]
    DC
    PAS
    610.0
    [m]
    DC
    PAS
    630.0
    [m]
    DC
    PAS
    650.0
    [m]
    DC
    PAS
    670.0
    [m]
    DC
    PAS
    690.0
    [m]
    DC
    PAS
    710.0
    [m]
    DC
    PAS
    730.0
    [m]
    DC
    PAS
    750.0
    [m]
    DC
    PAS
    780.0
    [m]
    DC
    PAS
    790.0
    [m]
    DC
    OD
    790.0
    [m]
    DC
    PAS
    800.0
    [m]
    DC
    OD
    810.0
    [m]
    DC
    OD
    810.0
    [m]
    DC
    820.0
    [m]
    DC
    OD
    830.0
    [m]
    DC
    OD
    840.0
    [m]
    DC
    OD
    850.0
    [m]
    DC
    OD
    860.0
    [m]
    DC
    OD
    870.0
    [m]
    DC
    OD
    870.0
    [m]
    DC
    880.0
    [m]
    DC
    OD
    890.0
    [m]
    DC
    OD
    900.0
    [m]
    DC
    OD
    910.0
    [m]
    DC
    OD
    920.0
    [m]
    DC
    OD
    930.0
    [m]
    DC
    OD
    940.0
    [m]
    DC
    OD
    950.0
    [m]
    DC
    OD
    950.0
    [m]
    DC
    PAS
    960.0
    [m]
    DC
    OD
    960.0
    [m]
    DC
    OD
    970.0
    [m]
    DC
    970.0
    [m]
    DC
    OD
    980.0
    [m]
    DC
    OD
    990.0
    [m]
    DC
    OD
    1000.0
    [m]
    DC
    OD
    1010.0
    [m]
    DC
    OD
    1020.0
    [m]
    DC
    OD
    1030.0
    [m]
    DC
    OD
    1030.0
    [m]
    DC
    PAS
    1050.0
    [m]
    DC
    PAS
    1070.0
    [m]
    DC
    PAS
    1090.0
    [m]
    DC
    PAS
    1112.0
    [m]
    DC
    PAS
    1140.0
    [m]
    DC
    PAS
    1142.5
    [m]
    SWC
    PAS
    1170.0
    [m]
    DC
    PAS
    1170.0
    [m]
    DC
    1185.0
    [m]
    DC
    PAS
    1203.0
    [m]
    DC
    PAS
    1218.0
    [m]
    DC
    PAS
    1225.0
    [m]
    SWC
    PAS
    1233.0
    [m]
    DC
    PAS
    1248.0
    [m]
    DC
    PAS
    1263.0
    [m]
    DC
    PAS
    1275.0
    [m]
    SWC
    PAS
    1278.0
    [m]
    DC
    PAS
    1293.0
    [m]
    DC
    PAS
    1308.0
    [m]
    DC
    PAS
    1323.0
    [m]
    DC
    PAS
    1338.0
    [m]
    DC
    PAS
    1353.0
    [m]
    DC
    PAS
    1368.0
    [m]
    DC
    PAS
    1374.0
    [m]
    SWC
    PAS
    1383.0
    [m]
    DC
    PAS
    1398.0
    [m]
    DC
    PAS
    1400.0
    [m]
    SWC
    PAS
    1413.0
    [m]
    DC
    PAS
    1428.0
    [m]
    DC
    PAS
    1443.0
    [m]
    DC
    PAS
    1458.0
    [m]
    DC
    PAS
    1473.0
    [m]
    DC
    PAS
    1479.0
    [m]
    SWC
    PAS
    1491.0
    [m]
    DC
    PAS
    1503.0
    [m]
    DC
    PAS
    1518.0
    [m]
    DC
    PAS
    1533.0
    [m]
    DC
    PAS
    1548.0
    [m]
    DC
    PAS
    1563.0
    [m]
    DC
    PAS
    1578.0
    [m]
    DC
    PAS
    1579.0
    [m]
    DC
    PAS
    1593.0
    [m]
    DC
    PAS
    1595.5
    [m]
    SWC
    PAS
    1608.0
    [m]
    DC
    PAS
    1615.0
    [m]
    SWC
    PAS
    1623.0
    [m]
    DC
    PAS
    1629.0
    [m]
    DC
    1638.0
    [m]
    DC
    PAS
    1653.0
    [m]
    DC
    PAS
    1664.0
    [m]
    SWC
    PAS
    1668.0
    [m]
    DC
    PAS
    1683.0
    [m]
    DC
    PAS
    1688.0
    [m]
    SWC
    PAS
    1698.0
    [m]
    DC
    PAS
    1728.0
    [m]
    DC
    PAS
    1741.0
    [m]
    SWC
    PAS
    1743.0
    [m]
    DC
    PAS
    1749.0
    [m]
    DC
    1758.0
    [m]
    DC
    PAS
    1773.0
    [m]
    DC
    PAS
    1788.0
    [m]
    DC
    PAS
    1796.0
    [m]
    SWC
    PAS
    1818.0
    [m]
    DC
    PAS
    1833.0
    [m]
    DC
    PAS
    1837.0
    [m]
    SWC
    PAS
    1848.0
    [m]
    DC
    PAS
    1851.0
    [m]
    DC
    1865.0
    [m]
    SWC
    PAS
    1873.5
    [m]
    SWC
    PAS
    1878.0
    [m]
    DC
    PAS
    1893.0
    [m]
    DC
    PAS
    1908.0
    [m]
    DC
    PAS
    1923.0
    [m]
    DC
    PAS
    1927.0
    [m]
    SWC
    PAS
    1938.0
    [m]
    DC
    PAS
    1950.0
    [m]
    DC
    1954.0
    [m]
    SWC
    PAS
    1956.0
    [m]
    DC
    OD
    1971.0
    [m]
    DC
    OD
    1977.0
    [m]
    DC
    OD
    1986.0
    [m]
    DC
    OD
    1995.0
    [m]
    DC
    OD
    2001.0
    [m]
    DC
    OD
    2016.0
    [m]
    DC
    OD
    2031.0
    [m]
    DC
    OD
    2031.5
    [m]
    SWC
    OD
    2037.0
    [m]
    DC
    OD
    2043.0
    [m]
    DC
    OD
    2058.0
    [m]
    DC
    OD
    2061.0
    [m]
    DC
    OD
    2074.5
    [m]
    SWC
    OD
    2076.0
    [m]
    DC
    OD
    2079.0
    [m]
    DC
    OD
    2082.0
    [m]
    DC
    OD
    2085.0
    [m]
    DC
    OD
    2091.0
    [m]
    DC
    OD
    2096.0
    [m]
    C
    OD
    2099.0
    [m]
    C
    OD
    2099.5
    [m]
    C
    OD
    2102.0
    [m]
    C
    OD
    2113.3
    [m]
    C
    OD
    2124.0
    [m]
    C
    OD
    2138.5
    [m]
    C
    OD
    2141.0
    [m]
    C
    OD
    2149.0
    [m]
    DC
    OD
    2168.0
    [m]
    C
    OD
    2184.0
    [m]
    C
    OD
    2185.0
    [m]
    C
    OD
    2185.0
    [m]
    C
    OD
    2200.0
    [m]
    C
    OD
    2200.3
    [m]
    C
    OD
    2202.4
    [m]
    C
    OD
    2212.5
    [m]
    C
    PAS
    2216.0
    [m]
    DC
    OD
    2216.5
    [m]
    C
    PAS
    2219.0
    [m]
    DC
    PAS
    2225.0
    [m]
    DC
    PAS
    2237.0
    [m]
    DC
    OD
    2240.0
    [m]
    DC
    PAS
    2255.0
    [m]
    DC
    PAS
    2255.0
    [m]
    DC
    OD
    2260.0
    [m]
    SWC
    PAS
    2270.0
    [m]
    DC
    PAS
    2276.0
    [m]
    DC
    OD
    2285.0
    [m]
    DC
    PAS
    2294.0
    [m]
    DC
    OD
    2303.0
    [m]
    DC
    PAS
    2315.0
    [m]
    SWC
    PAS
    2315.0
    [m]
    DC
    OD
    2330.0
    [m]
    DC
    PAS
    2333.0
    [m]
    DC
    OD
    2345.0
    [m]
    DC
    PAS
    2354.0
    [m]
    DC
    OD
    2360.0
    [m]
    DC
    PAS
    2375.0
    [m]
    DC
    PAS
    2375.0
    [m]
    DC
    OD
    2390.0
    [m]
    DC
    PAS
    2393.0
    [m]
    DC
    OD
    2405.0
    [m]
    DC
    PAS
    2414.0
    [m]
    DC
    OD
    2420.0
    [m]
    DC
    PAS
    2435.0
    [m]
    DC
    PAS
    2438.0
    [m]
    DC
    OD
    2450.0
    [m]
    DC
    PAS
    2459.0
    [m]
    DC
    OD
    2465.0
    [m]
    DC
    PAS
    2480.0
    [m]
    DC
    PAS
    2480.0
    [m]
    DC
    OD
    2501.0
    [m]
    DC
    OD
    2510.0
    [m]
    DC
    PAS
    2522.0
    [m]
    DC
    OD
    2525.0
    [m]
    DC
    PAS
    2527.5
    [m]
    SWC
    PAS
    2540.0
    [m]
    DC
    PAS
    2543.0
    [m]
    DC
    OD
    2555.0
    [m]
    DC
    PAS
    2570.0
    [m]
    DC
    PAS
    2585.0
    [m]
    DC
    OD
    2588.0
    [m]
    DC
    PAS

  • 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
    DST1
    2092.00
    2097.00
    20.07.1982 - 17:00
    YES

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.41

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    1.56
    pdf
    4.84
    pdf
    0.28
    pdf
    7.99
    pdf
    1.91

  • 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
    14.07
    pdf
    1.59

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    2092
    2097
    17.5
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    10.000
    17.000
    72
    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
    17
    470000
    0.778
    0.679
    26880

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    BGT GR
    533
    802
    CAL GR
    525
    802
    CAL GR
    525
    802
    CAL GR
    533
    772
    CBL
    1520
    2491
    CBL
    2050
    2592
    CBL VDL
    270
    772
    CST
    1105
    1664
    CST
    1688
    1962
    CST
    2031
    2575
    DLL MSFL GR
    2050
    2217
    HDT
    332
    2592
    ISF SONIC GR SP CAL
    332
    790
    ISF SONIC GR SP CAL
    1677
    2592
    ISF SONIC MSFL GR SP CAL
    792
    1684
    LDT CNL GR CAL
    1677
    2592
    LDT GR CAL
    792
    1682
    RFT
    1677
    2221
    VELOCITY
    385
    2590

  • 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
    332.0
    36
    333.0
    0.00
    LOT
    SURF.COND.
    20
    735.0
    26
    752.0
    0.00
    LOT
    INTERM.
    13 3/8
    792.0
    17 1/2
    800.0
    1.65
    LOT
    INTERM.
    9 5/8
    1675.0
    12 1/4
    1682.0
    1.72
    LOT
    LINER
    7
    2590.0
    8 1/2
    2590.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    333
    1.05
    spud mud
    750
    1.10
    49.0
    40.0
    water based
    802
    1.20
    45.0
    14.0
    water based
    1682
    1.45
    48.0
    14.0
    water based
    2085
    1.45
    48.0
    21.0
    water based
    2218
    1.45
    50.0
    13.0
    water based
    2590
    1.45
    52.0
    12.0
    water based

  • 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