Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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22.11.2024 - 09:09
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31/6-1

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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.
    31/6-1
    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.
    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.
    31/6-1
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    ST 8007 - 123 SP 1175
    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.
    381-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,
    15.07.1983
    Completed date
    Exploration wellbores from moveable facilities:
    For floating facilities - date when anchor handling is started. For jackups - date the jacking-down started. Exploration wellbores from fixed facilities and all development wellbores:
    Date when the wellbore is at total depth, and last casing, liner or screen is set. In case of immediate plugging of the wellbore, completed date equals the date the last plug i set in the wellbore.
    Date when the wellbore is at total depth, and last casing, liner or screen is set. In case of immediate plugging of the wellbore, completed date equals the date the last plug i set in the wellbore.
    28.10.1983
    Release date
    Date when raw data which has been reported to the authorities from the wellbore is not confidential any longer. Normally 2 years after finishing the drilling. May be earlier if the area of the production license is relinquished.
    28.10.1985
    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.
    15.02.2006
    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/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.
    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.
    LATE 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.
    SOGNEFJORD 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.
    FENSFJORD 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.
    302.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4070.0
    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).
    4070.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    6.25
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    132
    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.
    PRE-DEVONIAN
    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.
    BASEMENT
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    60° 38' 44.89'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    3° 40' 52.28'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6723687.94
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    537253.60
    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.
    22

  • Wellbore history
    General
    The primary objectives of the wildcat 31/6-1 was to test Late and Middle Jurassic sandstones on the main culmination of the Troll east structure in the western part of block 31/6. Secondary objectives were Middle to Early Jurassic and Triassic sandstones and a possible sandstone reservoir of pre-Triassic age within a set of tilted fault blocks buried by Triassic strata. The Troll east structure is a large tilted fault block containing Jurassic and older strata. The closure
    at Sognefjord Formation level is delineated by a flatspot covering most of the 31/6 block. The flatspot was expected to be a gas/fluid contact evident on the seismic and penetrated by nine wells in the Troll West area to the NNW in block 31/2. Planned TD of the well was 3800 m into rocks of pre-Triassic (? Devonian age).
    Operations and results
    Wildcat well 31/6-1 was spudded with the semi-submersible installation Nortrym on 15 July 1983 and drilled to TD at 4070 m in pre-Devonian basement rock. Problems with getting logging tools past the 30" casing shoe occurred due to gumbo problems. Further drilling went forth without major problems. The well was drilled with spud mud down to 425 m, with seawater / prehydrated gel and hi-vis pills from 425 m to 749 m, and with KCl/polymer/PHPA mud from 749 m to TD
    The total net sand in the Viking Group (1352-1805 m) found to be 424.25 m giving a net/gross ratio of 0.94 m with an average porosity of 27.5%. The Sognefjord Formation (1352-1488 m), the Heather Formation Unit B, (1488-1517.5 m) and the upper part of the Fensfjord Formation were found gas bearing from 1352 to 1571 m where the gas/oil contact was found. Below this a thin (3 m) oil zone was present with an oil/water contact at approximately 1574 m. The hydrocarbon-bearing reservoir consisted of very fine to fine grained sandstones, occasionally medium to coarse. They were generally friable to loose with a few tight calcite cemented stringers. The gross hydrocarbon column is 222 m and the net pay was calculated to be 198 m with an average porosity of 28.7% and an average water saturation of 19.1%.
    Triassic rocks (Hegre Group) were encountered at 2155.5 m. The basal part of the Triassic was characterized by homogenous shales, which were easily distinguished on wire line logs by their high gamma ray (100 - 120 API units). The shales are moderate brown to red brown, micromicaceous, silty and predominantly much more calcareous than the overlying interval. This interval has been dated as Scythian to Anisian down to 3925 m, (?) Scythian to 3978 m and indeterminate down to crystalline basement rocks of indeterminate age at 4013 m. The middle to lower Jurassic and Triassic sandstones were found water bearing.
    FMT pressure recordings and sampling were performed over the reservoir interval. A few pressure readings were also taken in the Cook Formation (Dunlin Group), but these were invalid and were not used for pressure gradient evaluations. The valid data gave a gas gradient of 0.012 bar/m (0.053 psi/ft) with an underlying water gradient of 0.099 bar/m (0.437 psi/ft). The interposed oil gradient is estimated to be 0.086 bar/m (0.38 psi/ft). FMT fluid samples were taken at 1371 m, (gas) 1444.6 m (gas), 1564.0 m (gas), 1564.6 m (gas), 1570.2 m (gas and water/mud filtrate), 1573.6 m (gas, 0.75 l oil, and water/mud filtrate), and 1576.5 m (no gas, 8.9 l water/mud filtrate). A total of 20 cores were cut continuously from the Heather Formation siltstone interval below the Draupne Formation down into the Fensfjord Formation sandstones, across the OWC in core no 17. A total of 235.4 m core was recovered. One 0.3 m core (core no 20) was cut in gneiss at TD. In addition to this, 225 sidewall cores were successfully recovered.
    The well was permanently abandoned on as a gas and oil discovery
    Testing
    Two production tests were successfully performed over two intervals in the gas zone. Both tests were gravel pack completions. DST No 1 (1562.5 - 1567.5 m) in the Fensfjord Formation in the lower part of the gas zone, produced 842000 Sm3/day) of 0.635 gravity gas (air =1) through a 22.2 mm choke (56/64"). DST No 2 (1435 - 1441 m) was performed in the lower part of the Sognefjord Formation and flowed 733000 Sm3 /day of gas through a 19 mm (48/64") choke. Gas gravity was 0.650. The pore pressure at the top of the reservoir was measured to be 156.06 bar (2263.5 psi). Maximum temperature recorded during DST1 was 69.4 deg C. Maximum temperature recorded during DST 2 was 64.4 deg C. This correspond to a ca 54 deg C/km linear gradient from the sea floor (assumed at 4 deg C) to top reservoir. This is a very high gradient compared to wells outside of the Troll field.

  • Cuttings at the Norwegian Offshore Directorate
    Cuttings at the Norwegian Offshore Directorate
    Cuttings available for sampling?
    NO
    Cuttings at the Norwegian Offshore Directorate
    Cutting sample, top depth [m]
    Cutting samples, bottom depth [m]
    430.00
    4070.00

  • 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
    2
    1349.0
    1350.0
    [m ]
    3
    1352.5
    1361.0
    [m ]
    4
    1361.5
    1370.7
    [m ]
    5
    1371.0
    1383.0
    [m ]
    6
    1389.0
    1407.3
    [m ]
    7
    1407.5
    1424.2
    [m ]
    8
    1425.5
    1440.5
    [m ]
    9
    1443.5
    1461.5
    [m ]
    10
    1461.0
    1477.1
    [m ]
    11
    1479.5
    1497.8
    [m ]
    12
    1498.0
    1514.6
    [m ]
    13
    1515.5
    1534.0
    [m ]
    14
    1534.0
    1542.7
    [m ]
    15
    1543.0
    1555.8
    [m ]
    16
    1561.0
    1561.9
    [m ]
    17
    1563.0
    1581.8
    [m ]
    18
    1581.5
    1588.5
    [m ]
    19
    1588.5
    1605.5
    [m ]
    20
    4070.0
    4070.8
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    234.0
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 1349-1350m
    Core photo at depth: 1352-1357m
    Core photo at depth: 1357-1361m
    Core photo at depth: 1361-1366m
    Core photo at depth: 1366-1370m
    1349-1350m
    1352-1357m
    1357-1361m
    1361-1366m
    1366-1370m
    Core photo at depth: 1371-1376m
    Core photo at depth: 1376-1381m
    Core photo at depth: 1381-1384m
    Core photo at depth: 1389-1394m
    Core photo at depth: 1394-1399m
    1371-1376m
    1376-1381m
    1381-1384m
    1389-1394m
    1394-1399m
    Core photo at depth: 1399-1404m
    Core photo at depth: 1404-1407m
    Core photo at depth: 1407-1412m
    Core photo at depth: 1412-1417m
    Core photo at depth: 1417-1422m
    1399-1404m
    1404-1407m
    1407-1412m
    1412-1417m
    1417-1422m
    Core photo at depth: 1422-1424m
    Core photo at depth: 1425-1430m
    Core photo at depth: 1430-1435m
    Core photo at depth: 1435-1440m
    Core photo at depth: 1443-1448m
    1422-1424m
    1425-1430m
    1430-1435m
    1435-1440m
    1443-1448m
    Core photo at depth: 1448-1453m
    Core photo at depth: 1453-1458m
    Core photo at depth: 1458-1461m
    Core photo at depth: 1461-1466m
    Core photo at depth: 1466-1471m
    1448-1453m
    1453-1458m
    1458-1461m
    1461-1466m
    1466-1471m
    Core photo at depth: 1471-1476m
    Core photo at depth: 1476-1477m
    Core photo at depth: 1479-1484m
    Core photo at depth: 1484-1489m
    Core photo at depth: 1489-1494m
    1471-1476m
    1476-1477m
    1479-1484m
    1484-1489m
    1489-1494m
    Core photo at depth: 1494-1497m
    Core photo at depth: 1498-1503m
    Core photo at depth: 1503-1508m
    Core photo at depth: 1508-1513m
    Core photo at depth: 1513-1514m
    1494-1497m
    1498-1503m
    1503-1508m
    1508-1513m
    1513-1514m
    Core photo at depth: 1515-1520m
    Core photo at depth: 1520-1525m
    Core photo at depth: 1525-1530m
    Core photo at depth: 1530-1534m
    Core photo at depth: 1534-1539m
    1515-1520m
    1520-1525m
    1525-1530m
    1530-1534m
    1534-1539m
    Core photo at depth: 1539-1542m
    Core photo at depth: 1543-1548m
    Core photo at depth: 1548-1553m
    Core photo at depth: 1553-1555m
    Core photo at depth: 1561-1562m
    1539-1542m
    1543-1548m
    1548-1553m
    1553-1555m
    1561-1562m
    Core photo at depth: 1563-1568m
    Core photo at depth: 1568-1573m
    Core photo at depth: 1573-1578m
    Core photo at depth: 1578-1581m
    Core photo at depth: 1581-1586m
    1563-1568m
    1568-1573m
    1573-1578m
    1578-1581m
    1581-1586m
    Core photo at depth: 1586-1588m
    Core photo at depth: 1588-1593m
    Core photo at depth: 1593-1598m
    Core photo at depth: 1598-1603m
    Core photo at depth: 1603-4070m
    1586-1588m
    1588-1593m
    1593-1598m
    1598-1603m
    1603-4070m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    440.0
    [m]
    DC
    RRI
    540.0
    [m]
    DC
    RRI
    640.0
    [m]
    DC
    RRI
    740.0
    [m]
    DC
    RRI
    840.0
    [m]
    DC
    RRI
    935.0
    [m]
    DC
    RRI
    1035.0
    [m]
    DC
    RRI
    1135.0
    [m]
    DC
    RRI
    1201.0
    [m]
    SWC
    IKU
    1210.0
    [m]
    SWC
    IKU
    1217.0
    [m]
    SWC
    IKU
    1221.0
    [m]
    SWC
    IKU
    1225.0
    [m]
    SWC
    IKU
    1230.0
    [m]
    SWC
    IKU
    1235.0
    [m]
    DC
    RRI
    1236.0
    [m]
    SWC
    IKU
    1239.0
    [m]
    SWC
    IKU
    1242.0
    [m]
    SWC
    IKU
    1245.0
    [m]
    SWC
    IKU
    1248.0
    [m]
    SWC
    IKU
    1251.0
    [m]
    SWC
    IKU
    1253.0
    [m]
    SWC
    IKU
    1255.0
    [m]
    SWC
    IKU
    1258.0
    [m]
    SWC
    IKU
    1262.0
    [m]
    SWC
    IKU
    1268.0
    [m]
    SWC
    IKU
    1271.0
    [m]
    SWC
    IKU
    1274.0
    [m]
    SWC
    IKU
    1277.0
    [m]
    SWC
    IKU
    1280.0
    [m]
    SWC
    IKU
    1283.0
    [m]
    SWC
    IKU
    1289.0
    [m]
    SWC
    IKU
    1292.0
    [m]
    SWC
    IKU
    1295.0
    [m]
    SWC
    IKU
    1298.0
    [m]
    SWC
    IKU
    1301.0
    [m]
    SWC
    IKU
    1304.0
    [m]
    SWC
    IKU
    1310.0
    [m]
    SWC
    IKU
    1324.0
    [m]
    SWC
    IKU
    1329.0
    [m]
    SWC
    IKU
    1332.0
    [m]
    DC
    RRI
    1335.0
    [m]
    SWC
    IKU
    1340.0
    [m]
    SWC
    IKU
    1346.0
    [m]
    SWC
    IKU
    1350.0
    [m]
    SWC
    IKU
    1430.2
    [m]
    C
    RRI
    1572.4
    [m]
    C
    RRI
    1606.0
    [m]
    SWC
    IKU
    1616.0
    [m]
    SWC
    IKU
    1625.0
    [m]
    SWC
    IKU
    1644.5
    [m]
    SWC
    IKU
    1670.0
    [m]
    DC
    RRI
    1671.0
    [m]
    SWC
    IKU
    1681.0
    [m]
    SWC
    IKU
    1690.0
    [m]
    SWC
    IKU
    1716.0
    [m]
    SWC
    IKU
    1734.0
    [m]
    SWC
    IKU
    1787.6
    [m]
    SWC
    IKU
    1808.0
    [m]
    SWC
    IKU
    1810.0
    [m]
    DC
    RRI
    1818.5
    [m]
    SWC
    IKU
    1836.0
    [m]
    SWC
    IKU
    1850.0
    [m]
    DC
    RRI
    1851.0
    [m]
    SWC
    IKU
    1863.0
    [m]
    SWC
    IKU
    1870.0
    [m]
    SWC
    RRI
    1874.0
    [m]
    SWC
    IKU
    1880.0
    [m]
    DC
    RRI
    1897.0
    [m]
    SWC
    IKU
    1900.0
    [m]
    DC
    RRI
    1913.0
    [m]
    SWC
    IKU
    1920.0
    [m]
    DC
    RRI
    1924.0
    [m]
    SWC
    IKU
    1930.0
    [m]
    DC
    RRI
    1933.0
    [m]
    SWC
    IKU
    1940.5
    [m]
    C
    RRI
    1944.0
    [m]
    SWC
    IKU
    1950.0
    [m]
    DC
    RRI
    1956.0
    [m]
    SWC
    IKU
    1960.0
    [m]
    DC
    RRI
    1960.7
    [m]
    DC
    RRI
    1972.0
    [m]
    SWC
    IKU
    1980.5
    [m]
    SWC
    IKU
    2106.0
    [m]
    SWC
    IKU
    2142.0
    [m]
    SWC
    IKU
    2170.0
    [m]
    DC
    RRI
    3552.0
    [m]
    DC
    OD
    3587.0
    [m]
    DC
    OD
    3622.0
    [m]
    DC
    OD
    3632.0
    [m]
    DC
    OD
    4047.0
    [m]
    DC
    OD

  • 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
    1562.50
    1567.50
    WATER
    29.09.1983 - 00:00
    YES
    DST
    DST2
    1435.00
    1441.00
    CONDENSATE
    18.10.1983 - 00:00
    YES
    DST
    DST 2
    1441.00
    1435.00
    CONDENSATE
    18.10.1983 - 00:00
    YES

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.63

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.96
    pdf
    0.25
    pdf
    6.56

  • 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
    22.24

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    1562
    1568
    22.2
    2.0
    1435
    1441
    19.0
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    2.0
    Drill stem tests (DST)
    Test number
    Oil
    [Sm3/day]
    Gas
    [Sm3/day]
    Oil density
    [g/cm3]
    Gas grav. rel.air
    GOR
    [m3/m3]
    1.0
    842000
    0.635
    2.0
    733000
    0.630

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL VOL
    800
    1310
    CDL CNL GR CAL
    1950
    4067
    CDL SPECTRALOG CNL GR CAL
    1295
    1978
    CFL CNL GR CAL
    425
    1318
    CST
    785
    1312
    CST
    1313
    1887
    CST
    1606
    1730
    CST
    1729
    1980
    CST
    2067
    4018
    CST
    2142
    3823
    DIFL LSBHC GR SP
    435
    4070
    DLL MLL
    1310
    1604
    FMT
    1338
    1594
    FMT
    1338
    1594
    FMT
    1371
    0
    FMT
    1444
    0
    FMT
    1564
    0
    FMT
    1564
    0
    FMT
    1570
    0
    FMT
    1573
    0
    FMT
    1576
    0
    HRD
    748
    4069
    PROLOG
    1300
    1700
    PROLOG
    1300
    1555
    VSP
    573
    4070

  • 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
    424.0
    36
    426.0
    0.00
    LOT
    SURF.COND.
    20
    748.0
    26
    765.0
    1.46
    LOT
    INTERM.
    13 3/8
    1310.0
    17 1/2
    1325.0
    1.68
    LOT
    INTERM.
    9 5/8
    1967.0
    12 1/4
    1980.0
    1.51
    LOT
    OPEN HOLE
    4070.0
    8 3/8
    4070.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    440
    1.13
    100.0
    seawater
    500
    1.07
    61.0
    seawater
    1000
    1.19
    46.0
    seawater
    1200
    1.23
    45.0
    seawater
    1340
    1.31
    44.0
    seawater
    1980
    1.10
    41.0
    seawater
    2400
    1.10
    42.0
    seawater
    3100
    1.11
    41.0
    seawater
    3800
    1.11
    46.0
    seawater
    4070
    1.11
    42.0
    seawater

  • 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