Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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25.11.2024 - 01:30
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34/7-21

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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.
    34/7-21
    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.
    34/7-21
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    SG 8431: ROW 211& COLUMN 1241
    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.
    747-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.
    54
    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,
    19.10.1992
    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.
    11.12.1992
    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.
    11.12.1994
    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.
    EARLY CRETACEOUS
    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.
    NO FORMAL NAME
    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.
    LATE 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.
    INTRA DRAUPNE FM SS
    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.
    192.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3015.0
    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).
    3014.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    4.3
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    106
    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.
    EARLY JURASSIC
    Oldest penetrated formation
    Name of the oldest lithostratigraphic unit penetrated by the wellbore. Shown only for released wells. In most wellbores this is formation or group at total depth. May differ from formation or group at TD for example in wellbores drilled with high deviation or through faults. Examples of legal values: AMUNDSEN FM, BALDER FM, BASEMENT, BLODØKS FM, BRYNE FM, BURTON FM, COOK FM, DRAKE FM, DRAUPNE FM, EKOFISK FM, DUNLIN GP.
    DRAKE FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    61° 17' 36.84'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 4' 21.14'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6796001.43
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    450299.76
    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.
    2026

  • Wellbore history
    General
    Exploration well 34/7-21 was drilled the south-western part of block 34/7 on Tampen Spur, on the H-prospect northwest of the Tordis Field. The main objective was to test the hydrocarbon prospectivity within the Late Jurassic (Viking Group) interval. The target was a Late Jurassic sand wedge, truncated in the up-dip direction towards the east by the Base Cretaceous Unconformity. Sufficient amounts of reservoir sand were conditioned by erosion and re-sedimentation from the underlying Middle Jurassic Brent Group, which is progressively truncated up-dip in the same direction. The secondary objective was to test the Paleocene in which an oil discovery had been made in well 34/7-18.
    Operations and results
    Well 34/7-21 was spudded with the semi-submersible installation Treasure Saga on 19 October 1992 and drilled to TD at 3015 m in the Early Jurassic Drake Formation. Tight and sticky formation was reported in the 12 1/4" section, but no significant technical problems occurred in the operations. Based on the site survey, possible shallow gas was predicted at 298, 548 and 612 m. The MWD confirmed a gas bearing sand at 541 m - 548 m. A flow check proved negative. The well was drilled with spud mud down to 1113 m and with KCl polymer mud from 1113 m to TD.
    In the Nordland, Hordaland, and Upper Rogaland Groups, the well penetrated mainly clay/claystone with minor sand, except for the sandy Utsira Formation between 929-1040 m. At the base of the Rogaland Group, the Lista Formation sandstone was encountered and proven dry, but with shows. In the Shetland and the condensed Cromer Knoll Group, claystone with limestone beds and massive marls/limestones were penetrated, respectively. A hydrocarbon-bearing interval was proven in a sand in the Cromer Knoll at 2498-2501 m. The top of the Late Jurassic reservoir was reached at 2508 m, which was 29 m shallower than prognosed. Within the Draupne Formation, two separate oil bearing sandstone intervals were proven between 2508-2545 m and between 2565.5-2569 m. The latter contained high concentrations of H2S. All three hydrocarbon bearing intervals had separate formation pressure regimes, and did not communicate. No OWC was identified at any level. The overall ODT was 2569 m (2543 m MSL).
    Apart from the three hydrocarbon bearing reservoirs shows were reported in several intervals. In the base of the Rogaland Group, traces of good oil shows were detected in argillaceous sandstones (intra Lista Formation) at 1850-1858 m. In the Shetland Group, good oil shows occurred in thin sandstone horizons from about 2270 m. The shows in this interval decreased progressively from below 2425 m. In the top of the Heather Formation, traces of weak oil shows was identified in a siltstone bed at 2587.5-2588.5 m. No shows were reported below this depth.
    A total of 5 cores were cut in well 34/7-21. Core 1 was cut in the interval 1858 to 1885.7 m in the Sele/Lista Formations. Cores 2-5 were cut in the Draupne Formation and down into the top of the Heather Formation, at 2515 to 2594 m.
    FMT fluid samples were taken at 2498.5 m (oil), 2529.7 m (oil), and at 2567.5 m (two samples in different runs, both with oil).
    After testing the well was plugged back and prepared for sidetracking to explore the extension of the Late Jurassic reservoirs. The plugged back hole was permanently abandoned on 11 December 1992 and the well was classified as an oil discovery.
    Testing
    The interval 2510.5-2537.5 m, covering the main part of the upper Intra-Draupne Sand, was perforated and tested. The oil rate at the end of the second main flow was measured to 884 Sm3/day through a 12.7 mm choke. The corresponding wellhead pressure was 146 bar and the GOR was 95 Sm/Sm3, while the dead oil density was 0.85 g cm3 and the gas gravity was 0.89 (air = 1). The reported bottom hole temperature/reservoir temperature from the test was 91 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]
    340.00
    3014.00

  • 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
    1858.0
    1880.7
    [m ]
    2
    2515.0
    2522.2
    [m ]
    3
    2530.0
    2547.0
    [m ]
    4
    2547.0
    2565.8
    [m ]
    5
    2566.0
    2592.2
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    91.9
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 1858-1862m
    Core photo at depth: 1862-1866m
    Core photo at depth: 1866-1870m
    Core photo at depth: 1870-1974m
    Core photo at depth: 1874-1878m
    1858-1862m
    1862-1866m
    1866-1870m
    1870-1974m
    1874-1878m
    Core photo at depth: 1878-1880m
    Core photo at depth: 2525-2519m
    Core photo at depth: 2519-2522m
    Core photo at depth: 2530-2534m
    Core photo at depth: 2534-2538m
    1878-1880m
    2525-2519m
    2519-2522m
    2530-2534m
    2534-2538m
    Core photo at depth: 2538-2542m
    Core photo at depth: 2542-2546m
    Core photo at depth: 2546-2547m
    Core photo at depth: 2547-2551m
    Core photo at depth: 2551-2555m
    2538-2542m
    2542-2546m
    2546-2547m
    2547-2551m
    2551-2555m
    Core photo at depth: 2555-2559m
    Core photo at depth: 2559-2563m
    Core photo at depth: 2563-2565m
    Core photo at depth: 2566-2570m
    Core photo at depth: 2570-2574m
    2555-2559m
    2559-2563m
    2563-2565m
    2566-2570m
    2570-2574m
    Core photo at depth: 2574-2578m
    Core photo at depth: 2578-2582m
    Core photo at depth: 2582-2586m
    Core photo at depth: 2586-2590m
    Core photo at depth: 2590-2592m
    2574-2578m
    2578-2582m
    2582-2586m
    2586-2590m
    2590-2592m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    350.0
    [m]
    DC
    PALEO
    380.0
    [m]
    DC
    PALEO
    410.0
    [m]
    DC
    PALEO
    440.0
    [m]
    DC
    PALEO
    470.0
    [m]
    DC
    PALEO
    500.0
    [m]
    DC
    PALEO
    530.0
    [m]
    DC
    PALEO
    560.0
    [m]
    DC
    PALEO
    590.0
    [m]
    DC
    PALEO
    620.0
    [m]
    DC
    PALEO
    650.0
    [m]
    DC
    PALEO
    680.0
    [m]
    DC
    PALEO
    710.0
    [m]
    DC
    PALEO
    740.0
    [m]
    DC
    PALEO
    770.0
    [m]
    DC
    PALEO
    800.0
    [m]
    DC
    PALEO
    830.0
    [m]
    DC
    PALEO
    860.0
    [m]
    DC
    PALEO
    890.0
    [m]
    DC
    PALEO
    920.0
    [m]
    DC
    PALEO
    950.0
    [m]
    DC
    PALEO
    980.0
    [m]
    DC
    PALEO
    1010.0
    [m]
    DC
    PALEO
    1040.0
    [m]
    DC
    PALEO
    1070.0
    [m]
    DC
    PALEO
    1100.0
    [m]
    DC
    PALEO
    1130.0
    [m]
    DC
    PALEO
    1160.0
    [m]
    DC
    PALEO
    1190.0
    [m]
    DC
    PALEO
    1220.0
    [m]
    DC
    PALEO
    1250.0
    [m]
    DC
    PALEO
    1280.0
    [m]
    DC
    PALEO
    1310.0
    [m]
    DC
    PALEO
    1340.0
    [m]
    DC
    PALEO
    1370.0
    [m]
    DC
    PALEO
    1400.0
    [m]
    DC
    PALEO
    1430.0
    [m]
    DC
    PALEO
    1460.0
    [m]
    DC
    PALEO
    1490.0
    [m]
    DC
    PALEO
    1520.0
    [m]
    DC
    PALEO
    1550.0
    [m]
    DC
    PALEO
    1580.0
    [m]
    DC
    PALEO
    1610.0
    [m]
    DC
    PALEO
    1640.0
    [m]
    DC
    PALEO
    1670.0
    [m]
    DC
    PALEO
    1700.0
    [m]
    DC
    PALEO
    1710.0
    [m]
    DC
    PALEO
    1720.0
    [m]
    DC
    PALEO
    1730.0
    [m]
    DC
    PALEO
    1740.0
    [m]
    DC
    PALEO
    1750.0
    [m]
    DC
    PALEO
    1760.0
    [m]
    DC
    PALEO
    1770.0
    [m]
    DC
    PALEO
    1780.0
    [m]
    DC
    PALEO
    1790.0
    [m]
    DC
    PALEO
    1800.0
    [m]
    DC
    PALEO
    1810.0
    [m]
    DC
    PALEO
    1815.0
    [m]
    DC
    PALEO
    1825.0
    [m]
    DC
    PALEO
    1835.0
    [m]
    DC
    PALEO
    1845.0
    [m]
    DC
    PALEO
    1855.0
    [m]
    DC
    PALEO
    1880.0
    [m]
    C
    RRI
    1885.0
    [m]
    DC
    PALEO
    1895.0
    [m]
    DC
    PALEO
    1915.0
    [m]
    DC
    PALEO
    1940.0
    [m]
    DC
    PALEO
    1975.0
    [m]
    DC
    PALEO
    2005.0
    [m]
    DC
    PALEO
    2035.0
    [m]
    DC
    PALEO
    2065.0
    [m]
    DC
    PALEO
    2095.0
    [m]
    DC
    PALEO
    2125.0
    [m]
    DC
    PALEO
    2155.0
    [m]
    DC
    PALEO
    2185.0
    [m]
    DC
    PALEO
    2215.0
    [m]
    DC
    PALEO
    2245.0
    [m]
    DC
    PALEO
    2275.0
    [m]
    DC
    PALEO
    2305.0
    [m]
    DC
    PALEO
    2335.0
    [m]
    DC
    PALEO
    2365.0
    [m]
    DC
    PALEO
    2395.0
    [m]
    DC
    PALEO
    2425.0
    [m]
    DC
    PALEO
    2455.0
    [m]
    DC
    PALEO
    2485.0
    [m]
    DC
    PALEO
    2515.0
    [m]
    DC
    PALEO
    2516.0
    [m]
    C
    PALEO
    2517.0
    [m]
    C
    PALEO
    2518.0
    [m]
    C
    PALEO
    2520.0
    [m]
    C
    RRI
    2531.0
    [m]
    C
    RRI
    2532.0
    [m]
    C
    RRI
    2533.0
    [m]
    C
    PALEO
    2541.0
    [m]
    C
    PALEO
    2548.0
    [m]
    C
    PALEO
    2556.0
    [m]
    C
    PALEO
    2557.0
    [m]
    C
    RRI
    2558.0
    [m]
    C
    RRI
    2560.0
    [m]
    C
    RRI
    2561.0
    [m]
    C
    RRI
    2563.0
    [m]
    C
    RRI
    2564.0
    [m]
    C
    PALEO
    2568.0
    [m]
    C
    RRI
    2569.0
    [m]
    C
    RRI
    2571.0
    [m]
    C
    PALEO
    2579.0
    [m]
    C
    PALEO
    2582.0
    [m]
    C
    PALEO
    2590.0
    [m]
    C
    PALEO
    2633.0
    [m]
    DC
    PALEO
    2648.0
    [m]
    DC
    PALEO
    2663.0
    [m]
    DC
    PALEO
    2688.0
    [m]
    DC
    PALEO
    2693.0
    [m]
    DC
    PALEO
    2708.0
    [m]
    DC
    PALEO
    2723.0
    [m]
    DC
    PALEO
    2753.0
    [m]
    DC
    PALEO
    2768.0
    [m]
    DC
    PALEO
    2783.0
    [m]
    DC
    PALEO
    2798.0
    [m]
    DC
    PALEO
    2813.0
    [m]
    DC
    PALEO
    2828.0
    [m]
    DC
    PALEO
    2843.0
    [m]
    DC
    PALEO
    2858.0
    [m]
    DC
    PALEO
    2873.0
    [m]
    DC
    PALEO
    2888.0
    [m]
    DC
    PALEO
    2918.0
    [m]
    DC
    PALEO
    2933.0
    [m]
    DC
    PALEO
    2948.0
    [m]
    DC
    PALEO
    2963.0
    [m]
    DC
    PALEO
    2978.0
    [m]
    DC
    PALEO
    2993.0
    [m]
    DC
    PALEO
    3008.0
    [m]
    DC
    PALEO
    3014.0
    [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
    TEST1
    0.00
    0.00
    OIL
    03.12.1992 - 09:10
    YES
    DST
    TEST2
    0.00
    0.00
    OIL
    05.12.1992 - 15:40
    YES

  • Lithostratigraphy

  • 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
    21.08

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    2510
    2537
    12.7
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    14.000
    32.000
    91
    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
    884
    0.850
    0.890
    95

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBIL GR
    1796
    1900
    CBIL GR
    2484
    2550
    CBIL GR
    2545
    2999
    DIPL ZDL CN GR
    1794
    2560
    DIPLOG GR
    1794
    3014
    DLL ACL ZDL GR
    1089
    1805
    DLL MLL GR
    1794
    2562
    DLL MLL GR
    2480
    3015
    DPIL DAC ZDL CN SL
    1795
    3015
    FMT GR
    1794
    3014
    FMT GR
    2510
    2538
    MWD CDR - GR RES DIR
    218
    3015
    SWC
    1853
    2978
    VELOCITY
    990
    2990

  • 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
    316.0
    36
    330.0
    0.00
    LOT
    INTERM.
    20
    1094.0
    26
    1113.0
    1.67
    LOT
    INTERM.
    13 3/8
    1795.0
    17 1/2
    1810.0
    1.85
    LOT
    INTERM.
    9 5/8
    2639.0
    12 1/4
    3015.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    326
    1.04
    WATER BASED
    330
    1.05
    WATER BASED
    675
    1.16
    4.0
    WATER BASED
    1110
    1.17
    5.0
    WATER BASED
    1113
    1.17
    6.0
    WATER BASED
    1122
    1.25
    22.0
    WATER BASED
    1404
    1.30
    32.0
    WATER BASED
    1763
    1.50
    41.0
    WATER BASED
    1810
    1.50
    42.0
    WATER BASED
    1858
    1.51
    39.0
    WATER BASED
    2081
    1.60
    49.0
    WATER BASED
    2196
    1.64
    60.0
    WATER BASED
    2307
    1.64
    53.0
    WATER BASED
    2510
    1.62
    41.0
    WATER BASED
    2530
    1.64
    50.0
    WATER BASED
    2552
    1.64
    43.0
    WATER BASED
    2566
    1.64
    44.0
    WATER BASED
    2594
    1.64
    38.0
    WATER BASED
    2601
    1.61
    39.0
    WATER BASED
    2635
    1.64
    42.0
    WATER BASED
    2654
    1.61
    39.0
    WATER BASED
    2971
    1.55
    36.0
    WATER BASED
    3015
    1.61
    38.0
    WATER BASED

  • Thin sections at the Norwegian Offshore Directorate
    Thin sections at the Norwegian Offshore Directorate
    Depth
    Unit
    1868.70
    [m ]
    1875.65
    [m ]
    2531.60
    [m ]
    2537.35
    [m ]
    2566.20
    [m ]
    2566.80
    [m ]
    2567.70
    [m ]
    2568.50
    [m ]
    2570.45
    [m ]
    2571.40
    [m ]
    2576.45
    [m ]

  • Pressure plots
    Pressure plots
    The pore pressure data is sourced from well logs if no other source is specified. In some wells where pore pressure logs do not exist, information from Drill stem tests and kicks have been used. The data has been reported to the NPD, and further processed and quality controlled by IHS Markit.
    Pressure plots
    Document name
    Document format
    Document size [MB]
    pdf
    0.22