Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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29.04.2024 - 01:33
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7120/8-1

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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.
    7120/8-1
    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.
    7120/8-1
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    LINE 513 - 134 SP: 2224.
    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.
    292-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.
    75
    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,
    28.06.1981
    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.
    10.09.1981
    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.
    10.09.1983
    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/CONDENSATE
    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.
    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.
    270.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2610.0
    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).
    2610.0
    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.
    95
    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° 24' 34.43'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    20° 26' 6.2'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7923384.58
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    479897.51
    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.
    120

  • Wellbore history
    General
    Wildcat well 7120/8-1 is located in the Snøhvit Field area. It was designed to test possible hydrocarbon accumulations in a seismic closure (Alpha prime structure) located to the east of a major N-S running fault in the western part of the block. The primary target was sandstone of Middle Jurassic age.
    Operations and results
    Well 7120/8-1 was spudded with the semi-submersible installation Ross Rig on 28 June 1981 and drilled to TD in Late Triassic rocks ((Fruholmen Formation). The 17 1/2" hole was drilled to 1128 m when the lower marine riser accidentally unlatched and two days of rig time were lost curing this problem before drilling could continue. When plugging back the well, gas bubbles were observed in the riser. Four days of rig time were lost before this problem was cured. Apart from this no significant difficulties were encountered and the well was drilled according to schedule. The well was drilled with spud mud down to 358 m, with gel mud from 358 m to 750 m, and with gel/lignosulphonate mud from 750 m to TD.
    Relatively dry gas was encountered at 2092 m in sandstone of the Middle to Early Jurassic Stø Formation. Log analysis, confirmed by RFT data, found a gas column down to a water contact at 2180 m. The reservoir sandstone showed good to excellent reservoir properties. Organic geochemical analyses showed TOC levels in the Early Cretaceous mudstones in the range ca 1.3 % to ca 5 %, generally increasing downwards to the base of the Cretaceous. Within the Late Jurassic Hekkingen Formation shales TOC increases from ca 3 % to at the top (1990 m) to more than 9 % at the base. In the Early Jurassic to Triassic below 2190 m occasional shales and thin coal beds have good potential for gas and oil, but are restricted in volume. The sediments are immature for petroleum generation down to ca 2000 m and marginally mature from this depth to TD. Kerogen is generally of Type II, with some addition of Type III in the lower part of Hekkingen Formation below 2012 m. Terrestrial input appears to be high in all potential source rock sequences in the well. Residual oil in the cored section showed a waxy, terrestrial signature. Seven cores were taken. Core 1 was cut in the Middle to Early Jurassic Stø Formation from 2112 m to 2121.5 m. The remaining cores were cut consecutively from 2171.5 m to 2270 m from the base of the Stø Formation and 80 m into the Early Jurassic Nordmela Formation. RFT samples were taken at 2168 m and 2094 m.
    The well was permanently abandoned on 10 September 1981 as a gas/condensate discovery.
    Testing
    Three drill stem tests were carried out in the hydrocarbon-bearing zone.
    DST 1 perforated 2165 m to 2172 m and produced 1056000 Sm3 gas and 54 m3 condensate per day on a 64/64" choke in the second flow period. The corresponding GOR is 19540 Sm3/Sm3. The gas gravity was 0.662 (air = 1) with 4.5 % CO2, and the condensate density was 0.777 g/cm3.
    DST perforated the two intervals 2133 m to 2138 m and 2140 m to 2150 m. This test produced 558000 Sm3 gas and 26.7 m3 condensate per day through a 64/64" choke in the second flow period. The corresponding GOR is 20900 Sm3/Sm3. The gas gravity was 0.666 (air = 1) with 5 % CO2, and the condensate density was 0.774 g/cm3.
    DST 3 perforated 2092 m to 2110 m and produced 954300 Sm3 gas and 53.5 m3 condensate per day through a 64/64" choke in the third flow period. The corresponding GOR is 17860 Sm3/Sm3. The gas gravity was 0.666 (air = 1) with 5 % CO2, and the condensate density was 0.780 g/cm3.
    No H2S was detected in any of the tests. The tests indicated a very dry gas condensate system. Dew point pressure was 209 barg (3031 psig). Density of reservoir fluid (at DP) was 0.156 g/cm3 (0.068 psi/ft).

  • 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]
    360.00
    2606.00

  • 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
    2112.0
    2121.4
    [m ]
    2
    2171.5
    2181.0
    [m ]
    3
    2181.0
    2195.0
    [m ]
    4
    2195.0
    2214.0
    [m ]
    5
    2214.0
    2232.8
    [m ]
    6
    2232.8
    2251.5
    [m ]
    7
    2251.5
    2270.0
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    107.9
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 2112-2115m
    Core photo at depth: 2115-2118m
    Core photo at depth: 2118-2121m
    Core photo at depth: 2121-2121m
    Core photo at depth: 2171-2174m
    2112-2115m
    2115-2118m
    2118-2121m
    2121-2121m
    2171-2174m
    Core photo at depth: 2174-2177m
    Core photo at depth: 2177-2180m
    Core photo at depth: 2180-2181m
    Core photo at depth: 2181-2184m
    Core photo at depth: 2184-2187m
    2174-2177m
    2177-2180m
    2180-2181m
    2181-2184m
    2184-2187m
    Core photo at depth: 2187-2190m
    Core photo at depth: 2193-2195m
    Core photo at depth: 2198-2201m
    Core photo at depth: 2201-2204m
    Core photo at depth: 2204-2207m
    2187-2190m
    2193-2195m
    2198-2201m
    2201-2204m
    2204-2207m
    Core photo at depth: 2207-2210m
    Core photo at depth: 2110-2113m
    Core photo at depth: 2213-2214m
    Core photo at depth: 2214-2217m
    Core photo at depth: 2217-2220m
    2207-2210m
    2110-2113m
    2213-2214m
    2214-2217m
    2217-2220m
    Core photo at depth: 2220-2223m
    Core photo at depth: 2223-2223m
    Core photo at depth: 2223-2226m
    Core photo at depth: 2226-2229m
    Core photo at depth: 2229-2232m
    2220-2223m
    2223-2223m
    2223-2226m
    2226-2229m
    2229-2232m
    Core photo at depth: 2232-2233m
    Core photo at depth: 2233-2235
    Core photo at depth: 2235-2238m
    Core photo at depth: 2238-2241m
    Core photo at depth: 2241-2244m
    2232-2233m
    2233-2235
    2235-2238m
    2238-2241m
    2241-2244m
    Core photo at depth: 2244-2247m
    Core photo at depth: 2247-2250m
    Core photo at depth: 2250-2251m
    Core photo at depth: 2251-2254m
    Core photo at depth: 2254-2257m
    2244-2247m
    2247-2250m
    2250-2251m
    2251-2254m
    2254-2257m
    Core photo at depth: 2257-2260m
    Core photo at depth: 2260-2263m
    Core photo at depth: 2263-2266m
    Core photo at depth: 2266-2269m
    Core photo at depth: 2269-2270m
    2257-2260m
    2260-2263m
    2263-2266m
    2266-2269m
    2269-2270m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    360.0
    [m]
    DC
    365.0
    [m]
    DC
    365.0
    [m]
    DC
    RRI
    400.0
    [m]
    DC
    RRI
    450.0
    [m]
    DC
    RRI
    495.0
    [m]
    DC
    RRI
    510.0
    [m]
    DC
    RRI
    525.0
    [m]
    DC
    RRI
    540.0
    [m]
    DC
    540.0
    [m]
    DC
    RRI
    545.0
    [m]
    DC
    555.0
    [m]
    DC
    RRI
    570.0
    [m]
    DC
    RRI
    585.0
    [m]
    DC
    RRI
    595.0
    [m]
    DC
    600.0
    [m]
    DC
    695.0
    [m]
    DC
    700.0
    [m]
    DC
    735.0
    [m]
    DC
    RRI
    765.0
    [m]
    DC
    RRI
    780.0
    [m]
    DC
    RRI
    795.0
    [m]
    DC
    RRI
    810.0
    [m]
    DC
    RRI
    825.0
    [m]
    DC
    RRI
    840.0
    [m]
    DC
    RRI
    855.0
    [m]
    DC
    RRI
    870.0
    [m]
    DC
    RRI
    885.0
    [m]
    DC
    RRI
    1035.0
    [m]
    DC
    1050.0
    [m]
    DC
    RRI
    1065.0
    [m]
    DC
    RRI
    1065.0
    [m]
    DC
    1080.0
    [m]
    DC
    RRI
    1095.0
    [m]
    DC
    RRI
    1095.0
    [m]
    DC
    1112.0
    [m]
    DC
    RRI
    1127.0
    [m]
    DC
    RRI
    1127.0
    [m]
    DC
    1142.0
    [m]
    DC
    RRI
    1157.0
    [m]
    DC
    RRI
    1157.0
    [m]
    DC
    1169.0
    [m]
    DC
    RRI
    1184.0
    [m]
    DC
    RRI
    1187.0
    [m]
    DC
    1202.0
    [m]
    DC
    RRI
    1208.0
    [m]
    DC
    OD
    1217.0
    [m]
    DC
    RRI
    1217.0
    [m]
    DC
    1220.0
    [m]
    DC
    OD
    1229.0
    [m]
    DC
    OD
    1232.0
    [m]
    DC
    RRI
    1238.0
    [m]
    DC
    OD
    1247.0
    [m]
    DC
    RRI
    1247.0
    [m]
    DC
    1250.0
    [m]
    DC
    OD
    1259.0
    [m]
    DC
    OD
    1262.0
    [m]
    DC
    RRI
    1277.0
    [m]
    DC
    RRI
    1277.0
    [m]
    DC
    1292.0
    [m]
    DC
    RRI
    1307.0
    [m]
    DC
    RRI
    1307.0
    [m]
    DC
    1322.0
    [m]
    DC
    RRI
    1337.0
    [m]
    DC
    RRI
    1470.0
    [m]
    SWC
    RRI
    1487.0
    [m]
    DC
    RRI
    1502.0
    [m]
    DC
    RRI
    1517.0
    [m]
    DC
    RRI
    1527.0
    [m]
    SWC
    RRI
    1533.0
    [m]
    DC
    RRI
    1538.0
    [m]
    DC
    RRI
    1568.0
    [m]
    DC
    RRI
    1581.0
    [m]
    SWC
    RRI
    1598.0
    [m]
    DC
    RRI
    1613.0
    [m]
    DC
    RRI
    1628.0
    [m]
    DC
    RRI
    1643.0
    [m]
    DC
    RRI
    1655.0
    [m]
    DC
    RRI
    1657.0
    [m]
    SWC
    RRI
    1673.0
    [m]
    DC
    RRI
    1688.0
    [m]
    DC
    RRI
    1718.0
    [m]
    DC
    RRI
    1730.0
    [m]
    SWC
    RRI
    1742.0
    [m]
    DC
    RRI
    1763.0
    [m]
    DC
    RRI
    1770.0
    [m]
    SWC
    RRI
    1778.0
    [m]
    DC
    RRI
    1785.0
    [m]
    SWC
    RRI
    1793.0
    [m]
    DC
    RRI
    1808.0
    [m]
    DC
    RRI
    1815.0
    [m]
    SWC
    RRI
    1823.0
    [m]
    SWC
    RRI
    1838.0
    [m]
    DC
    RRI
    1850.0
    [m]
    DC
    RRI
    1855.0
    [m]
    SWC
    RRI
    1868.0
    [m]
    DC
    RRI
    1877.0
    [m]
    DC
    RRI
    1877.0
    [m]
    DC
    1898.0
    [m]
    DC
    RRI
    1901.0
    [m]
    SWC
    RRI
    1907.0
    [m]
    DC
    1913.0
    [m]
    DC
    RRI
    1928.0
    [m]
    DC
    RRI
    1937.0
    [m]
    SWC
    RRI
    1937.0
    [m]
    DC
    1943.0
    [m]
    SWC
    RRI
    1958.0
    [m]
    DC
    RRI
    1967.0
    [m]
    DC
    1973.0
    [m]
    DC
    RRI
    1991.0
    [m]
    SWC
    RRI
    1997.0
    [m]
    DC
    1999.0
    [m]
    SWC
    RRI
    2003.0
    [m]
    DC
    RRI
    2008.0
    [m]
    SWC
    RRI
    2018.0
    [m]
    SWC
    RRI
    2027.0
    [m]
    DC
    RRI
    2036.5
    [m]
    SWC
    RRI
    2048.0
    [m]
    DC
    RRI
    2061.0
    [m]
    SWC
    RRI
    2065.5
    [m]
    SWC
    RRI
    2069.0
    [m]
    SWC
    RRI
    2075.0
    [m]
    SWC
    RRI
    2082.0
    [m]
    SWC
    RRI
    2084.0
    [m]
    DC
    RRI
    2087.0
    [m]
    SWC
    RRI
    2115.4
    [m]
    C
    RRI
    2117.7
    [m]
    C
    RRI
    2118.0
    [m]
    SWC
    RRI
    2119.5
    [m]
    C
    RRI
    2129.5
    [m]
    SWC
    RRI
    2137.0
    [m]
    SWC
    RRI
    2139.0
    [m]
    SWC
    RRI
    2172.0
    [m]
    C
    RRI
    2175.4
    [m]
    C
    RRI
    2178.0
    [m]
    C
    RRI
    2180.9
    [m]
    C
    RRI
    2186.6
    [m]
    C
    RRI
    2186.9
    [m]
    C
    RRI
    2187.4
    [m]
    C
    RRI
    2190.0
    [m]
    C
    RRI
    2193.6
    [m]
    C
    RRI
    2197.5
    [m]
    C
    RRI
    2201.5
    [m]
    C
    RRI
    2204.0
    [m]
    C
    RRI
    2205.5
    [m]
    C
    RRI
    2207.9
    [m]
    C
    RRI
    2210.8
    [m]
    C
    RRI
    2213.6
    [m]
    C
    RRI
    2213.9
    [m]
    C
    RRI
    2216.6
    [m]
    C
    RRI
    2219.4
    [m]
    C
    RRI
    2222.7
    [m]
    C
    RRI
    2226.8
    [m]
    C
    RRI
    2228.5
    [m]
    C
    RRI
    2229.8
    [m]
    C
    RRI
    2232.7
    [m]
    C
    RRI
    2234.9
    [m]
    C
    RRI
    2235.4
    [m]
    C
    RRI
    2238.6
    [m]
    C
    RRI
    2241.2
    [m]
    C
    RRI
    2248.0
    [m]
    C
    RRI
    2248.1
    [m]
    C
    RRI
    2251.3
    [m]
    C
    RRI
    2254.4
    [m]
    C
    RRI
    2256.7
    [m]
    C
    RRI
    2260.2
    [m]
    C
    RRI
    2263.4
    [m]
    C
    RRI
    2265.7
    [m]
    C
    RRI
    2266.9
    [m]
    C
    RRI
    2268.5
    [m]
    C
    RRI
    2270.0
    [m]
    DC
    RRI
    2270.0
    [m]
    C
    RRI
    2273.0
    [m]
    DC
    RRI
    2279.0
    [m]
    DC
    RRI
    2282.0
    [m]
    DC
    RRI
    2291.0
    [m]
    DC
    RRI
    2294.0
    [m]
    DC
    RRI
    2297.0
    [m]
    DC
    RRI
    2300.0
    [m]
    SWC
    RRI
    2300.0
    [m]
    DC
    RRI
    2306.0
    [m]
    DC
    RRI
    2312.0
    [m]
    DC
    RRI
    2322.0
    [m]
    SWC
    RRI
    2339.0
    [m]
    DC
    RRI
    2346.5
    [m]
    SWC
    RRI
    2359.0
    [m]
    DC
    RRI
    2372.0
    [m]
    DC
    RRI
    2390.0
    [m]
    DC
    RRI
    2417.0
    [m]
    DC
    RRI
    2428.5
    [m]
    SWC
    RRI
    2447.0
    [m]
    DC
    RRI
    2462.0
    [m]
    DC
    RRI
    2477.0
    [m]
    DC
    RRI
    2492.0
    [m]
    DC
    RRI
    2495.0
    [m]
    SWC
    RRI
    2521.0
    [m]
    SWC
    RRI
    2534.0
    [m]
    DC
    RRI
    2567.0
    [m]
    DC
    RRI
    2573.0
    [m]
    SWC
    RRI
    2582.0
    [m]
    DC
    RRI
    2591.0
    [m]
    SWC
    RRI
    2597.0
    [m]
    DC
    RRI
    2608.0
    [m]
    SWC
    RRI
    2609.0
    [m]
    DC
    RRI

  • 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
    2165.00
    2172.00
    20.08.1981 - 13:00
    YES
    DST
    DST2
    2133.00
    2138.00
    26.08.1981 - 19:00
    YES
    DST
    DST3
    2093.00
    2110.00
    31.08.1981 - 04:00
    YES

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.44

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    7.34
    pdf
    3.53

  • 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
    13.01
    pdf
    1.77

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    2165
    2172
    36.0
    2.0
    2133
    2138
    25.0
    3.0
    2093
    2110
    25.0
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    80
    2.0
    72
    3.0
    78
    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
    48
    1049000
    0.777
    0.662
    21854
    2.0
    27
    557000
    0.779
    0.666
    20629
    3.0
    50
    953000
    0.780
    0.666
    19060

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL
    500
    1807
    CBL
    1450
    2530
    CBL
    1850
    2160
    CST
    770
    1815
    CST
    1823
    2018
    CST
    2018
    2129
    CST
    2132
    2608
    CST
    2300
    2519
    DLL MSFL
    2025
    2270
    FDC CNL GR CAL
    734
    2610
    HDT GEODIP
    734
    2607
    ISF SONIC GR SP
    270
    747
    ISF SONIC GR SP MSFL
    734
    2610
    RFT
    2094
    2264
    VELOCITY
    550
    2600

  • 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
    357.0
    36
    359.0
    0.00
    LOT
    SURF.COND.
    20
    735.0
    26
    750.0
    1.49
    LOT
    INTERM.
    13 3/8
    1807.0
    17 1/2
    1822.0
    1.64
    LOT
    INTERM.
    9 5/8
    2593.0
    12 1/4
    2610.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    575
    1.04
    40.0
    18.0
    spud mud
    1086
    1.25
    40.0
    14.0
    water based
    2121
    1.40
    46.0
    11.0
    water based
    2181
    1.45
    48.0
    11.0
    water based
    2238
    1.36
    46.0
    10.0
    water based
    2610
    1.30
    50.0
    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