Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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16.07.2024 - 01:28
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34/7-12

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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.
    34/7-12
    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.
    NORTH 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.
    34/7-12
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    SG 8431 ROW 155 COLUMN 534
    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.
    Saga Petroleum ASA
    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.
    567-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.
    68
    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,
    11.10.1987
    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.
    17.12.1987
    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.
    17.12.1989
    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.
    28.02.2008
    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.
    MIDDLE 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.
    TARBERT 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.
    MIDDLE 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.
    NESS FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    26.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    190.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2784.0
    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).
    2780.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    5.4
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    100
    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.
    LUNDE FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    61° 16' 17.86'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 6' 47.26'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6793527.52
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    452441.55
    UTM zone
    Universal Transverse Mercator zone. Examples of legal values: 31, 32, 33, 34.
    31
    NPDID wellbore
    Norwegian Offshore Directorate's unique id for the wellbore.
    1187
  • Wellbore history

    >
    Well 34/7-12 is a replacement well for well 34/7-11, which was junked for technical reasons. It is located in the Tampen Spur area in the Northern North Sea. Its overall purpose was to assess the hydrocarbon potential in the "B"-structure in the southern part of the block. The primary objectives were to establish the thickness and reservoir quality of the prospective Brent the Brent Group in Group, and to determine the OWC. The secondary objectives were to assess the potential of the Dunlin Cook Formation reservoir, the Statfjord Formation and the upper part of the Triassic Lunde unit B/C reservoir section. TD was prognosed to 2900 m.
    Operations and results
    Wildcat well 34/7-12 was spudded 20 m north of the 34/7-11 location. It was drilled with the semi-submersible installation Treasure Saga on 11 October 1987 and drilled to TD at 2784 m in the Late Triassic Lunde Formation. The well was drilled without significant technical problems. The well was drilled with spud mud down to 852 m and with KCl mud from 852 m to TD.
    The Brent Group came in at 2169 m, and Statfjord Formation at 2606 m. Lunde Formation was encountered at 2763 m. Oil/water contact was defined in the Ness Formation at 2250 m.
    The Brent Group, from 2169 to 2340.5 m (171.5 m thick) comprised the sandy Tarbert Formation,the interbedded shaly and sandy Ness Formation, the sandy Etive and Rannoch Formations and at the base the conglomeratic Broom Formation. The Dunlin Group was penetrated from 2340.5 to 2606 m (265.5 m thick), comprising the shaly Drake Formation at the top, the Cook Formation with interbedded sandstone and claystone, the Burton Formation with claystone and minor sandstone and the Amundsen and Calcareous Amundsen Formations having clay stones with minor limestone. The Statfjord Formation, 157 m thick from 2606 to 2763 m, was dominated by sandstones with minor to interbedded claystone. The Late Triassic upper Lunde Formation was encountered at 2763 m, and comprised clay stone interbedded with siltstone.
    The Brent Group was hydrocarbon-bearing through the Tarbert Formation and into the Ness Formation with an OWC at 2250 m, confirmed by logs and FMT pressure gradients. Shows were seen down to 2268 m. In addition, shows were reported from a sidewall core cut at 1803 m in a Paleocene sand. Logs also indicated the presence of a two metre thick residual or hydrocarbon bearing zone from 1801 m to 1803 m. Shows were also reported in siltstones in the interval 2060 to 2142 m in the Late Cretaceous Kyrre Formation. No indications of hydrocarbons were reported below 2268 m.
    A total of 10 cores were cut from 2169 to 2360.5 m in the Brent Group and 20 m into the Dunlin Group. A total of 180.8 m core was recovered (94.4 % of cored section). FMT segregated fluid samples were taken at 2171 m (oil and gas), 2171.5 m (oil and gas), 2189.5 m (two samples in different runs, both with oil and gas), 2249.5 m (gas and oil-cut mud), and at 2252.5 m (water). The samples from 2171 and 2189.5 m were analysed and found to be very similar with oil densities close to 0.845 g/cm3, gas gravities in the range 0.863 to 0.879, and CO2 contents in the range 0.22 to 0.29 %.
    The well was permanently abandoned on 17 December 1987 as an oil discovery.
    Testing
    Three drill stem tests were performed in well 34/7-12.
    DST 1 tested the interval 2276.2 - 2282.2 m in the Rannoch Formation and produced up to1297 Sm3 water/day through a 12.7 mm choke. Up to 10% sand production was reported in the beginning of the main flow period. Maximum down-hole temperature recorded (at 2230.7 m) was 84.2 deg C.
    DST 2 tested the interval 2229 - 2235 m in the Ness Formation. On a 12.7 mm choke this test produced 881 Sm3 oil and 59383 Sm3 gas /day. The corresponding GOR was 68 Sm3/Sm3, the oil density was 0.841 g/cm3, and the gas gravity was 0.722 (air = 1). Maximum down-hole temperature recorded (at 2202.6 m) was 83.4 deg C.
    DST 3 tested the interval 2205.5 - 2209.5 m in the lower Tarbert Formation. On a 14.3 mm choke this test produced 1460 Sm3 oil and 96450 Sm3 gas /day. The corresponding GOR was 68 Sm3/Sm3, the oil density was 0.840 g/cm3, and the gas gravity was 0.695 (air = 1). Maximum down-hole temperature recorded (at 2161.3 m) was 82.1 deg C.
  • 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]
    860.00
    2784.00
  • 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
    2169.0
    2196.3
    [m ]
    2
    2196.5
    2212.9
    [m ]
    3
    2214.0
    2215.5
    [m ]
    4
    2216.0
    2224.9
    [m ]
    5
    2228.0
    2242.4
    [m ]
    6
    2242.0
    2261.5
    [m ]
    7
    2262.0
    2289.9
    [m ]
    8
    2290.0
    2305.0
    [m ]
    9
    2305.5
    2332.5
    [m ]
    10
    2333.0
    2356.6
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    181.5
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES
  • Core photos

    Core photos
    Core photo at depth: 2169-2174m
    Core photo at depth: 2174-2179m
    Core photo at depth: 2179-2184m
    Core photo at depth: 2184-2189m
    Core photo at depth: 2189-2194m
    2169-2174m
    2174-2179m
    2179-2184m
    2184-2189m
    2189-2194m
    Core photo at depth: 2194-2198m
    Core photo at depth: 2196-2201m
    Core photo at depth: 2201-2206m
    Core photo at depth: 2206-2211m
    Core photo at depth: 2211-2212m
    2194-2198m
    2196-2201m
    2201-2206m
    2206-2211m
    2211-2212m
    Core photo at depth: 2214-2215m
    Core photo at depth: 2216-2221m
    Core photo at depth: 2221-2224m
    Core photo at depth: 2228-2233m
    Core photo at depth: 2233-2238m
    2214-2215m
    2216-2221m
    2221-2224m
    2228-2233m
    2233-2238m
    Core photo at depth: 2238-2242m
    Core photo at depth: 2242-2247m
    Core photo at depth: 2247-2252m
    Core photo at depth: 2252-2257m
    Core photo at depth: 2257-2261m
    2238-2242m
    2242-2247m
    2247-2252m
    2252-2257m
    2257-2261m
    Core photo at depth: 2262-2267m
    Core photo at depth: 2267-2272m
    Core photo at depth: 2272-2277m
    Core photo at depth: 2277-2282m
    Core photo at depth: 2282-2287m
    2262-2267m
    2267-2272m
    2272-2277m
    2277-2282m
    2282-2287m
    Core photo at depth: 2287-2289m
    Core photo at depth: 2290-2295m
    Core photo at depth: 2295-2300m
    Core photo at depth: 2300-2305m
    Core photo at depth: 2305-2310m
    2287-2289m
    2290-2295m
    2295-2300m
    2300-2305m
    2305-2310m
    Core photo at depth: 2310-2315m
    Core photo at depth: 2315-2320m
    Core photo at depth: 2320-2325m
    Core photo at depth: 2325-2330m
    Core photo at depth: 2330-2332m
    2310-2315m
    2315-2320m
    2320-2325m
    2325-2330m
    2330-2332m
    Core photo at depth: 2333-2338m
    Core photo at depth: 2338-2343m
    Core photo at depth: 2343-2348m
    Core photo at depth: 2348-2353m
    Core photo at depth: 2353-2356m
    2333-2338m
    2338-2343m
    2343-2348m
    2348-2353m
    2353-2356m
  • Palynological slides at the Norwegian Offshore Directorate

    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1010.0
    [m]
    DC
    PALEO
    1021.0
    [m]
    DC
    PALEO
    1025.0
    [m]
    DC
    PALEO
    1040.0
    [m]
    DC
    PALEO
    1050.0
    [m]
    DC
    PALEO
    1070.0
    [m]
    DC
    PALEO
    1080.0
    [m]
    DC
    PALEO
    1099.5
    [m]
    DC
    PALEO
    1100.0
    [m]
    DC
    PALEO
    1110.0
    [m]
    DC
    PALEO
    1130.0
    [m]
    DC
    PALEO
    1140.0
    [m]
    DC
    PALEO
    1150.0
    [m]
    DC
    PALEO
    1160.0
    [m]
    DC
    PALEO
    1170.0
    [m]
    DC
    PALEO
    1190.0
    [m]
    DC
    PALEO
    1200.0
    [m]
    DC
    PALEO
    1220.0
    [m]
    DC
    PALEO
    1228.0
    [m]
    DC
    PALEO
    1230.0
    [m]
    DC
    PALEO
    1250.0
    [m]
    DC
    PALEO
    1270.0
    [m]
    DC
    PALEO
    1280.0
    [m]
    DC
    PALEO
    1300.0
    [m]
    DC
    PALEO
    1310.0
    [m]
    DC
    PALEO
    1330.0
    [m]
    DC
    PALEO
    1340.0
    [m]
    DC
    PALEO
    1360.0
    [m]
    DC
    PALEO
    1370.0
    [m]
    DC
    PALEO
    1390.0
    [m]
    DC
    PALEO
    1400.0
    [m]
    DC
    PALEO
    1420.0
    [m]
    DC
    PALEO
    1430.0
    [m]
    DC
    PALEO
    1450.0
    [m]
    DC
    PALEO
    1460.0
    [m]
    DC
    PALEO
    1480.0
    [m]
    DC
    PALEO
    1490.0
    [m]
    DC
    PALEO
    1510.0
    [m]
    DC
    PALEO
    1520.0
    [m]
    DC
    PALEO
    1540.0
    [m]
    DC
    PALEO
    1550.0
    [m]
    DC
    PALEO
    1570.0
    [m]
    DC
    PALEO
    1580.0
    [m]
    DC
    PALEO
    1600.0
    [m]
    DC
    PALEO
    1610.0
    [m]
    DC
    PALEO
    1630.0
    [m]
    DC
    PALEO
    1640.0
    [m]
    DC
    PALEO
    1660.0
    [m]
    DC
    PALEO
    1670.0
    [m]
    DC
    PALEO
    1690.0
    [m]
    DC
    PALEO
    1696.0
    [m]
    SWC
    PALEO
    1700.0
    [m]
    DC
    PALEO
    1710.0
    [m]
    DC
    PALEO
    1730.0
    [m]
    DC
    PALEO
    1740.0
    [m]
    DC
    PALEO
    1760.0
    [m]
    DC
    PALEO
    1770.0
    [m]
    DC
    PALEO
    1790.0
    [m]
    DC
    PALEO
    1800.0
    [m]
    DC
    PALEO
    1815.0
    [m]
    DC
    PALEO
    1830.0
    [m]
    DC
    PALEO
    1845.0
    [m]
    DC
    PALEO
    1860.0
    [m]
    DC
    PALEO
    1875.0
    [m]
    DC
    PALEO
    1890.0
    [m]
    DC
    PALEO
    1900.0
    [m]
    SWC
    PALEO
    1905.0
    [m]
    DC
    PALEO
    1920.0
    [m]
    DC
    PALEO
    1935.0
    [m]
    DC
    PALEO
    1950.0
    [m]
    DC
    PALEO
    1965.0
    [m]
    DC
    PALEO
    1980.0
    [m]
    DC
    PALEO
    1995.0
    [m]
    DC
    PALEO
    2010.0
    [m]
    DC
    PALEO
    2025.0
    [m]
    DC
    PALEO
    2040.0
    [m]
    DC
    PALEO
    2055.0
    [m]
    DC
    PALEO
    2070.0
    [m]
    DC
    PALEO
    2085.0
    [m]
    DC
    PALEO
    2100.0
    [m]
    DC
    PALEO
    2115.0
    [m]
    DC
    PALEO
    2130.0
    [m]
    DC
    PALEO
    2145.0
    [m]
    DC
    PALEO
    2160.0
    [m]
    DC
    PALEO
    2162.0
    [m]
    DC
    PALEO
    2171.5
    [m]
    DC
    PALEO
    2175.0
    [m]
    DC
    PALEO
    2178.8
    [m]
    DC
    PALEO
    2198.8
    [m]
    DC
    PALEO
    2209.5
    [m]
    DC
    PALEO
    2214.5
    [m]
    DC
    PALEO
    2218.8
    [m]
    DC
    PALEO
    2220.8
    [m]
    DC
    PALEO
    2223.8
    [m]
    DC
    PALEO
    2229.5
    [m]
    DC
    PALEO
    2237.8
    [m]
    DC
    PALEO
    2243.0
    [m]
    DC
    PALEO
    2258.7
    [m]
    DC
    PALEO
    2279.5
    [m]
    DC
    PALEO
    2299.0
    [m]
    DC
    PALEO
    2305.8
    [m]
    DC
    PALEO
    2313.0
    [m]
    DC
    PALEO
    2319.5
    [m]
    DC
    PALEO
    2326.4
    [m]
    DC
    PALEO
    2341.0
    [m]
    DC
    PALEO
    2348.0
    [m]
    DC
    PALEO
    2350.9
    [m]
    DC
    PALEO
    2353.1
    [m]
    DC
    PALEO
    2355.8
    [m]
    DC
    PALEO
    2358.0
    [m]
    DC
    PALEO
    2364.0
    [m]
    DC
    PALEO
    2373.0
    [m]
    DC
    PALEO
    2391.0
    [m]
    DC
    PALEO
    2433.0
    [m]
    DC
    PALEO
    2451.0
    [m]
    DC
    PALEO
    2460.0
    [m]
    DC
    PALEO
    2490.0
    [m]
    DC
    PALEO
    2505.0
    [m]
    DC
    PALEO
    2520.0
    [m]
    DC
    PALEO
    2534.0
    [m]
    DC
    PALEO
    2553.0
    [m]
    DC
    PALEO
    2555.0
    [m]
    DC
    PALEO
    2563.0
    [m]
    DC
    PALEO
    2580.0
    [m]
    DC
    PALEO
    2622.0
    [m]
    DC
    PALEO
    2634.0
    [m]
    DC
    PALEO
    2640.0
    [m]
    DC
    PALEO
    2670.0
    [m]
    DC
    PALEO
    2682.0
    [m]
    DC
    PALEO
    2727.0
    [m]
    DC
    PALEO
    2742.0
    [m]
    DC
    PALEO
    2754.0
    [m]
    DC
    PALEO
    2768.0
    [m]
    DC
    PALEO
    2772.0
    [m]
    DC
    PALEO
    2784.0
    [m]
    DC
    PALEO
  • 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
    DST2
    2229.00
    2235.00
    03.12.1987 - 11:30
    YES
    DST
    DST3
    2205.50
    2209.50
    10.12.1987 - 23:00
    YES
  • Lithostratigraphy

  • Geochemical information

    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.74
    pdf
    2.43
  • 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
    8.97
    pdf
    1.67
  • Drill stem tests (DST)

    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    2276
    2282
    12.7
    2.0
    2229
    2235
    12.7
    3.0
    2206
    2210
    14.3
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    15.000
    49.000
    84
    2.0
    19.000
    43.000
    83
    3.0
    23.000
    48.000
    82
    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
    1685
    2.0
    881
    59000
    0.841
    0.722
    68
    3.0
    1460
    96000
    0.840
    0.695
    66
  • Logs

    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    ACBL
    600
    1852
    CDL CNL GR
    2100
    2479
    CDL GR
    837
    1836
    CNL CDL GR
    1852
    2784
    CNL CDL GR
    2140
    2784
    COREGUN
    858
    1848
    COREGUN
    1875
    2775
    DIFL LS BHC GR
    837
    1852
    DIFL LS BHC GR
    1852
    2784
    DIPMETER
    1850
    2784
    DLL MLL GR
    2100
    2476
    DLL MLL GR
    2125
    2784
    FMT
    2171
    2312
    FMT
    2210
    2474
    FMT
    2210
    2692
    MWD - GR RES DIR
    327
    2781
    VELOCITY
    1525
    2784
  • 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
    327.0
    36
    379.0
    0.00
    LOT
    SURF.COND.
    20
    838.0
    26
    852.0
    1.66
    LOT
    INTERM.
    13 3/8
    1851.0
    17 1/2
    1870.0
    2.23
    LOT
    INTERM.
    9 5/8
    2366.0
    12 1/4
    2784.0
    0.00
    LOT
  • Drilling mud

    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    332
    1.05
    WATER BASED
    14.10.1987
    378
    1.13
    5.0
    12.0
    WATER BASED
    28.10.1987
    852
    1.05
    20.0
    10.1
    WATER BASED
    28.10.1987
    852
    1.05
    22.0
    8.7
    WATER BASED
    28.10.1987
    852
    1.17
    5.0
    13.5
    WATER BASED
    21.10.1987
    852
    1.20
    6.0
    12.5
    WATER BASED
    21.10.1987
    852
    1.15
    6.0
    13.5
    WATER BASED
    28.10.1987
    870
    1.09
    18.0
    8.7
    WATER BASED
    28.10.1987
    1335
    1.17
    22.0
    10.6
    WATER BASED
    28.10.1987
    1544
    1.25
    25.0
    12.0
    WATER BASED
    26.10.1987
    1865
    1.58
    34.0
    12.0
    WATER BASED
    26.10.1987
    1865
    1.58
    35.0
    11.5
    WATER BASED
    28.10.1987
    1865
    1.58
    35.0
    12.5
    WATER BASED
    28.10.1987
    1870
    1.58
    32.0
    10.6
    WATER BASED
    28.10.1987
    2106
    1.72
    32.0
    8.7
    WATER BASED
    29.10.1987
    2120
    1.72
    24.0
    6.8
    WATER BASED
    14.12.1987
    2155
    1.72
    24.0
    6.8
    WATER BASED
    16.12.1987
    2180
    1.72
    27.0
    6.3
    WATER BASED
    30.10.1987
    2214
    1.72
    31.0
    7.2
    WATER BASED
    02.11.1987
    2224
    1.72
    24.0
    6.8
    WATER BASED
    08.12.1987
    2234
    1.72
    29.0
    5.3
    WATER BASED
    02.11.1987
    2267
    1.72
    25.0
    6.8
    WATER BASED
    08.12.1987
    2267
    1.72
    28.0
    6.3
    WATER BASED
    08.12.1987
    2276
    1.72
    30.0
    4.8
    WATER BASED
    03.11.1987
    2313
    1.72
    30.0
    6.3
    WATER BASED
    10.11.1987
    2330
    1.72
    30.0
    7.2
    WATER BASED
    25.11.1987
    2330
    1.72
    30.0
    7.2
    WATER BASED
    23.11.1987
    2330
    1.72
    30.0
    7.2
    WATER BASED
    23.11.1987
    2357
    1.72
    30.0
    5.3
    WATER BASED
    10.11.1987
    2366
    1.72
    28.0
    5.3
    WATER BASED
    10.11.1987
    2381
    1.72
    31.0
    10.6
    WATER BASED
    20.11.1987
    2480
    1.70
    28.0
    5.3
    WATER BASED
    10.11.1987
    2480
    1.72
    28.0
    4.8
    WATER BASED
    10.11.1987
    2480
    1.72
    27.0
    6.3
    WATER BASED
    10.11.1987
    2510
    1.72
    25.0
    5.8
    WATER BASED
    10.11.1987
    2595
    1.72
    26.0
    6.3
    WATER BASED
    10.11.1987
    2609
    1.72
    22.0
    5.3
    WATER BASED
    11.11.1987
    2622
    1.72
    23.0
    5.3
    WATER BASED
    12.11.1987
    2655
    1.72
    25.0
    5.3
    WATER BASED
    13.11.1987
    2705
    1.72
    25.0
    6.3
    WATER BASED
    16.11.1987
    2778
    1.72
    28.0
    6.3
    WATER BASED
    16.11.1987
    2784
    1.72
    28.0
    6.8
    WATER BASED
    16.11.1987
    2784
    1.72
    28.0
    6.8
    WATER BASED
    17.11.1987
    2784
    1.72
    26.0
    6.3
    WATER BASED
    18.11.1987
    2784
    1.72
    26.0
    6.3
    WATER BASED
    19.11.1987
  • 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
    0.22