Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
25.11.2024 - 01:30
Time of last synchronization with Norwegian Offshore Directorate's internal systems

34/8-10 S

Export: PDF icon PDF

  • General information
    General information
    Attribute Value
    Wellbore name
    Official name of wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    34/8-10 S
    Type
    Wellbore type. Legal values: EXPLORATION, DEVELOPMENT, OTHER (see 'Purpose' for more information)
    EXPLORATION
    Purpose
    Final classification of the wellbore.

    Legal values for exploration wellbores:
    WILDCAT, APPRAISAL, WILDCAT-CCS, APPRAISAL-CCS.

    Legal values for development wellbores:
    OBSERVATION, PRODUCTION, INJECTION, INJECTION-CCS, OBSERVATION-CCS.

    Legal values for other wellbores:
    SOIL DRILLING (drilling in connection with track surveys and other subsurface surveys to investigate the soil conditions prior to placement of facilities),
    SHALLOW GAS (drilling to investigate shallow gas before the first 'real' drilling on the location),
    PILOT (drilling to investigate the geology and fluid connectors for location of the main wellbore),
    SCIENTIFIC (drilling according to Law of Scientific research and exploration),
    STRATIGRAPHIC (driling according to Law of Petroleum activities §2-1).
    APPRAISAL
    Status
    Status for the wellbore. Legal values are:

    BLOWOUT: A blowout has occurred in the well.
    CLOSED: A development wellbore that has been closed in a shorter or longer periode. Also applies to development wellbores where drilling is completed, but production/injection has not yet been reported.
    DRILLING: The well is in the drilling phase - can be active drilling, logging, testing or plugging,
    JUNKED: The drilling operation has been terminated due to technical problems.
    P&A: Exploration: The well is plugged and abandoned, and can not be reentered for further use. Development wells: The production/injection from/to the well is stopped and the well is plugged. The wellhead is removed or else made unavailable for further well operations.
    PLUGGED: The wellbore has been plugged, but the upper parts of the wellbore can be re-used. A sidetrack might be drilled at a later stage.
    PRODUCING: It was produced from the wellbore at the time of the operators last monthly report to the Norwegian Offshore Directorate.
    INJECTING: It was injected to the wellbore at the time of the operators last monthly report to the Norwegian Offshore Directorate.
    PREDRILLED: The upper part of the well has been drilled, usually as part of a batch-drilling campaign covering several wellbores.
    RE-CLASS TO DEV: Exploration wellbore that is reclassified to a development wellbore.
    RE-CLASS TO TEST: Exploration wellbore that is reclassified to test production.
    SUSPENDED: The drilling operation in the wellbore has been temporarily stopped. The current plan is to continue drilling later on.
    P&A
    Factmaps in new window
    Main area
    Name of the area on the Norwegian Continental Shelf where the wellbore is located. Legal values: BARENTS SEA, NORWEGIAN SEA, NORTH SEA.
    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.
    34/8-10
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    NH-9001-3D:ROW 770 & COLUMN 658
    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.
    768-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.
    73
    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,
    28.09.1993
    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.
    09.12.1993
    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.
    09.12.1995
    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.
    10.01.2012
    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.
    APPRAISAL
    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.
    NO
    1st level with HC, age
    Age of lithostratigraphic unit, 1st level, where hydrocarbons were encountered. Examples of legal values: CRETACEOUS, EARLY CRETACEOUS, LATE JURASSIC, EOCENE. See also Norwegian Offshore Directorate bulletins.
    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.
    BRENT GP
    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.
    EARLY 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.
    DUNLIN GP
    3rd level with HC, age
    Age of lithostratigraphic unit, 3rd level, where hydrocarbons were encountered. Examples of legal values: CRETACEOUS, EARLY CRETACEOUS, LATE JURASSIC, EOCENE.
    LATE TRIASSIC
    3rd level with HC, formation
    Name of lithostartigraphic unit, 3rd 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.
    LUNDE FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    23.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    326.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3470.0
    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).
    3316.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    44.8
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    122
    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° 21' 17.3'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 27' 19.5'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6802591.77
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    470873.63
    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.
    2179

  • Wellbore history
    General
    Well 34/8-10 S was drilled to appraise the 34/8-1 Visund discovery on Tampen Spur in the Northern North Sea. The objectives were to confirm the presence of mobile hydrocarbons and the pressure regime in the SI segment (Statfjord Formation); to confirm the absence of free gas cap and also pressure regime and fluid composition in the NI segment (BrentGroup); to improve stratigraphic control of base Cretaceous, the A-Central Fault, top Statfjord and top Lunde; and to characterise the Lunde B/C aquifer and pressure regime.
    Operations and results
    Appraisal well 34/8-10 S was spudded with the semi-submersible installation Polar Pioneer on 28 September 1993 and drilled to TD at 3470 m (3316 m TVD) in the Late Triassic Lunde Formation. The well was drilled with an angle of 37 degrees through the reservoir to achieve the objectives. It was drilled with seawater and hi-vis pills down to 1358 m, and with Anco 2000 glycol mud from 1358 m to TD.
    The well penetrated oil-bearing sandstones in all the potential reservoirs: Brent-NI, Amundsen-SI, Statfjord-SI and Lunde-SI. The Brent Group was penetrated at 2879.5 m in a heavily faulted area. It was represented by the Rannoch Formation from 2879.5 to 2885 m and by Etive Formation from 2888 to 2896.5 m with a fault slice identified as Drake Formation in between (2885-2888 m). A gross reservoir thickness of 14 m was defined, giving a net pay of 10 m. The pressure in the Brent Group was found to be higher than previously documented, and in addition the oil was of a lighter composition. No free gas cap was found in the Brent sandstones.
    The Amundsen Sandstone was not expected to be penetrated as the well was planned to cut the A-Central fault very close to the Statfjord Formation. However, the well showed that top Statfjord was about 20 m deeper and the A-Central fault about 50 m further to the east than prognosed. The Amundsen Sandstone member was encountered from 2993 m to 3006 m. Core and wire line log data confirm this unit as oil-bearing with a gross reservoir thickness of 12.5m giving a net pay of 11.5m.
    Good oil shows were observed in the Rannoch and Etive Formations from 2877 to 2893m. Poor to moderate shows were seen from 2919 to 3018 m on sandstones of Dunlin Group. Good to very good shows were observed in the Statfjord Formation from 3036 - 3122 m. Poor to moderate shows were seen in the Lunde A and B/C sandstones from 3141 to 3256 m (ODT) and below 3255 m residual shows were observed. The Statfjord Formation was encountered at 3038.5 m, and was cored all through. Wire line logs and core data show the presence of oil in Statfjord sandstones with a net thickness of sand of 60 m and a net pay of 56.5 m
    Lunde A Formation was penetrated from 3125 to 3243 m and Lunde B/C from 3243 m to TD. Core and wire line data proved Lunde to be oil-bearing down to 3256 m (ODT) in this well with a net sand thickness of 52.5 m and a net pay of 8.5 m.
    All in all, 203 m core was cut in 23 cores at different intervals throughout the well. MDT fluid samples were taken at 1951.8 m, 2891.5 m, 3002.8 m, and at 3255.0 m
    The well was permanently abandoned on 9.December 1993 as an oil appraisal well.
    Testing
    A production test (Test no 1) was performed in the intervals 3039 - 3052 m and 3062-3087.5 m (2983 - 3021 m TVD all across) in the Statfjord Formation sandstones. A 5 day main flow period produced 1180 Sm3 oil and 414000 Sm3 gas/day with a FWHP of 210.4 bar and a GOR of 350 Sm3/Sm3 through a 44/64" fixed choke with an average permeability of 1370 mD. The density of oil was recorded as 0.82 g/cc, while the gas gravity was 0.755 (air = 1) 1.4% CO2 and 2.6 ppm H2S. The temperature measured in the flow was114 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]
    1370.00
    3470.00

  • 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
    1924.0
    1925.8
    [m ]
    2
    1926.0
    1941.5
    [m ]
    3
    2874.0
    2878.1
    [m ]
    4
    2880.0
    2884.7
    [m ]
    5
    2884.7
    2894.9
    [m ]
    6
    2894.9
    2897.4
    [m ]
    7
    2913.5
    2917.4
    [m ]
    8
    2917.4
    2919.4
    [m ]
    9
    2922.0
    2924.8
    [m ]
    10
    2996.0
    3002.2
    [m ]
    11
    3002.2
    3029.9
    [m ]
    12
    3029.9
    3042.0
    [m ]
    13
    3042.0
    3053.6
    [m ]
    14
    3053.6
    3058.6
    [m ]
    15
    3058.6
    3083.4
    [m ]
    16
    3084.5
    3085.6
    [m ]
    17
    3086.5
    3097.2
    [m ]
    18
    3097.5
    3111.4
    [m ]
    19
    3114.6
    3122.8
    [m ]
    20
    3122.8
    3123.8
    [m ]
    21
    3124.0
    3129.3
    [m ]
    22
    3130.5
    3147.0
    [m ]
    23
    3270.0
    3281.6
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    203.2
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 1924-1925m
    Core photo at depth: 1926-1930m
    Core photo at depth: 1930-1934m
    Core photo at depth: 1934-1938m
    Core photo at depth: 1938-1941m
    1924-1925m
    1926-1930m
    1930-1934m
    1934-1938m
    1938-1941m
    Core photo at depth: 2874-2878m
    Core photo at depth: 2880-2884m
    Core photo at depth: 2884-2889m
    Core photo at depth: 2889-2894m
    Core photo at depth: 2894-2895m
    2874-2878m
    2880-2884m
    2884-2889m
    2889-2894m
    2894-2895m
    Core photo at depth: 2894-2897m
    Core photo at depth: 2913-2917m
    Core photo at depth: 2917-2919m
    Core photo at depth: 2922-2924m
    Core photo at depth: 2996-3001m
    2894-2897m
    2913-2917m
    2917-2919m
    2922-2924m
    2996-3001m
    Core photo at depth: 3001-3002m
    Core photo at depth: 3002-3007m
    Core photo at depth: 3007-3012m
    Core photo at depth: 3012-3017m
    Core photo at depth: 3017-3022m
    3001-3002m
    3002-3007m
    3007-3012m
    3012-3017m
    3017-3022m
    Core photo at depth: 3022-3027m
    Core photo at depth: 3027-3029m
    Core photo at depth: 3029-3034m
    Core photo at depth: 3034-3039m
    Core photo at depth: 3039-3042m
    3022-3027m
    3027-3029m
    3029-3034m
    3034-3039m
    3039-3042m
    Core photo at depth: 3042-3047m
    Core photo at depth: 3047-3052m
    Core photo at depth: 3052-3053m
    Core photo at depth: 3053-3058m
    Core photo at depth: 3058-3059m
    3042-3047m
    3047-3052m
    3052-3053m
    3053-3058m
    3058-3059m
    Core photo at depth: 3058-3063m
    Core photo at depth: 3063-3068m
    Core photo at depth: 3068-3073m
    Core photo at depth: 3073-3078m
    Core photo at depth: 3078-3083m
    3058-3063m
    3063-3068m
    3068-3073m
    3073-3078m
    3078-3083m
    Core photo at depth: 3083-3084m
    Core photo at depth: 3084-3085m
    Core photo at depth: 3086-3091m
    Core photo at depth: 3091-3096m
    Core photo at depth: 3096-3097m
    3083-3084m
    3084-3085m
    3086-3091m
    3091-3096m
    3096-3097m
    Core photo at depth: 3097-3102m
    Core photo at depth: 3102-3107m
    Core photo at depth: 3107-3111m
    Core photo at depth: 3114-3119m
    Core photo at depth: 3119-3122m
    3097-3102m
    3102-3107m
    3107-3111m
    3114-3119m
    3119-3122m
    Core photo at depth: 3122-3123m
    Core photo at depth: 3124-3129m
    Core photo at depth: 3129-3130m
    Core photo at depth: 3130-3135m
    Core photo at depth: 3135-3140m
    3122-3123m
    3124-3129m
    3129-3130m
    3130-3135m
    3135-3140m
    Core photo at depth: 3140-3145m
    Core photo at depth: 3145-3147m
    Core photo at depth: 3270-3275m
    Core photo at depth: 3275-3280m
    Core photo at depth: 3280-3282m
    3140-3145m
    3145-3147m
    3270-3275m
    3275-3280m
    3280-3282m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1370.0
    [m]
    DC
    SPT
    1390.0
    [m]
    DC
    SPT
    1410.0
    [m]
    DC
    SPT
    1430.0
    [m]
    DC
    SPT
    1450.0
    [m]
    DC
    SPT
    1500.0
    [m]
    DC
    SPT
    1520.0
    [m]
    DC
    SPT
    1540.0
    [m]
    DC
    SPT
    1580.0
    [m]
    DC
    SPT
    1600.0
    [m]
    DC
    SPT
    1620.0
    [m]
    DC
    SPT
    1640.0
    [m]
    DC
    SPT
    1660.0
    [m]
    DC
    SPT
    1670.0
    [m]
    DC
    SPT
    1726.0
    [m]
    SWC
    SPT
    1740.0
    [m]
    DC
    SPT
    1760.0
    [m]
    DC
    SPT
    1780.0
    [m]
    DC
    SPT
    1800.0
    [m]
    DC
    SPT
    1820.0
    [m]
    DC
    SPT
    1840.0
    [m]
    DC
    SPT
    1880.0
    [m]
    DC
    SPT
    1900.0
    [m]
    DC
    SPT
    1920.0
    [m]
    DC
    SPT
    1924.0
    [m]
    C
    SPT
    1936.0
    [m]
    C
    SPT
    1941.5
    [m]
    C
    SPT
    1953.0
    [m]
    SWC
    SPT
    1957.3
    [m]
    SWC
    SPT
    1966.0
    [m]
    SWC
    SPT
    2030.0
    [m]
    DC
    SPT
    2060.0
    [m]
    DC
    SPT
    2080.0
    [m]
    DC
    SPT
    2100.0
    [m]
    DC
    SPT
    2120.0
    [m]
    DC
    SPT
    2140.0
    [m]
    DC
    SPT
    2160.0
    [m]
    DC
    SPT
    2180.0
    [m]
    DC
    SPT
    2220.0
    [m]
    DC
    SPT
    2260.0
    [m]
    DC
    SPT
    2280.0
    [m]
    DC
    SPT
    2300.0
    [m]
    DC
    SPT
    2560.0
    [m]
    DC
    SPT
    2628.0
    [m]
    SWC
    SPT
    2650.0
    [m]
    SWC
    SPT
    2669.0
    [m]
    SWC
    SPT
    2700.0
    [m]
    SWC
    SPT
    2724.0
    [m]
    SWC
    SPT
    2750.0
    [m]
    SWC
    SPT
    2870.0
    [m]
    SWC
    SPT
    2872.0
    [m]
    DC
    SPT
    2875.3
    [m]
    C
    SPT
    2875.5
    [m]
    C
    SPT
    2876.2
    [m]
    C
    SPT
    2876.7
    [m]
    C
    SPT
    2877.3
    [m]
    C
    SPT
    2882.0
    [m]
    DC
    SPT
    2883.0
    [m]
    C
    SPT
    2894.9
    [m]
    C
    SPT
    2896.0
    [m]
    C
    SPT
    2896.6
    [m]
    C
    SPT
    2897.4
    [m]
    C
    SPT
    2914.0
    [m]
    C
    SPT
    2916.0
    [m]
    C
    SPT
    2923.0
    [m]
    C
    SPT
    2930.0
    [m]
    SWC
    SPT
    2940.0
    [m]
    SWC
    SPT
    2944.0
    [m]
    SWC
    SPT
    2952.0
    [m]
    SWC
    SPT
    2954.0
    [m]
    SWC
    SPT
    2959.0
    [m]
    SWC
    SPT
    2964.0
    [m]
    SWC
    SPT
    2971.0
    [m]
    SWC
    SPT
    2978.0
    [m]
    SWC
    SPT
    3033.0
    [m]
    C
    SPT
    3050.0
    [m]
    C
    SPT
    3056.0
    [m]
    C
    SPT
    3058.0
    [m]
    C
    SPT
    3122.8
    [m]
    C
    SPT
    3312.0
    [m]
    DC
    SPT
    3460.0
    [m]
    DC
    SPT
    3470.0
    [m]
    DC
    SPT

  • 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
    0.00
    0.00
    24.11.1993 - 05:20
    YES

  • Lithostratigraphy

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.29
    pdf
    1.43
    pdf
    0.75

  • 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
    24.49

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    3039
    3052
    17.4
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    114
    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
    1180
    414000
    0.823
    0.755
    350

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL VDL
    1500
    3385
    CST GR
    1419
    2240
    CST GR
    2628
    3254
    DLL MSFL EPT LSS NGT SP AMS
    2554
    3472
    DLL MSFL LDL CNL LSS GR SP AMS
    434
    1360
    DLL MSFL LDL CNL LSS NGT SP AMS
    1348
    2560
    FMI GR ACTS
    2554
    3472
    LDL CNL GR
    2554
    3472
    MDT GR AMS
    1952
    1968
    MDT GR AMS
    2995
    3082
    MDT GR AMS
    3255
    3255
    MWD - GR RES DIR
    361
    1353
    MWD DPR - GR RES DIR
    1353
    3470
    VSP
    740
    2550
    VSP
    2280
    3410

  • 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
    434.0
    36
    434.0
    0.00
    LOT
    INTERM.
    13 3/8
    1348.0
    17 1/2
    1358.0
    1.69
    LOT
    INTERM.
    9 5/8
    2552.0
    12 1/4
    2560.0
    1.88
    LOT
    LINER
    7
    3468.0
    8 1/2
    3470.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    390
    1.60
    22.0
    9.5
    WATER BASED
    09.12.1993
    434
    1.05
    WATER BASED
    30.09.1993
    1110
    1.62
    23.0
    9.5
    WATER BASED
    08.12.1993
    1358
    1.20
    WATER BASED
    30.09.1993
    1358
    1.20
    WATER BASED
    01.10.1993
    1358
    1.20
    WATER BASED
    04.10.1993
    1358
    1.20
    WATER BASED
    04.10.1993
    1633
    1.40
    17.0
    13.5
    WATER BASED
    04.10.1993
    1900
    1.42
    16.0
    16.0
    WATER BASED
    06.10.1993
    2202
    1.50
    24.0
    17.5
    WATER BASED
    07.10.1993
    2560
    1.50
    25.0
    16.0
    WATER BASED
    11.10.1993
    2560
    1.50
    23.0
    12.0
    WATER BASED
    11.10.1993
    2560
    1.51
    20.0
    11.0
    WATER BASED
    12.10.1993
    2560
    1.50
    23.0
    16.0
    WATER BASED
    08.10.1993
    2560
    1.52
    22.0
    17.0
    WATER BASED
    11.10.1993
    2571
    1.50
    18.0
    11.0
    WATER BASED
    13.10.1993
    2653
    1.50
    26.0
    15.0
    WATER BASED
    14.10.1993
    2741
    1.61
    27.0
    15.0
    WATER BASED
    18.10.1993
    2818
    1.65
    38.0
    16.0
    WATER BASED
    18.10.1993
    2874
    1.70
    33.0
    13.0
    WATER BASED
    18.10.1993
    2885
    1.70
    34.0
    12.0
    WATER BASED
    19.10.1993
    2900
    1.70
    31.0
    14.0
    WATER BASED
    20.10.1993
    2923
    1.69
    32.0
    13.0
    WATER BASED
    22.10.1993
    2940
    1.69
    33.0
    14.0
    WATER BASED
    25.10.1993
    2990
    1.69
    29.0
    13.0
    WATER BASED
    25.10.1993
    3010
    1.69
    28.0
    13.0
    WATER BASED
    26.10.1993
    3015
    1.69
    28.0
    13.0
    WATER BASED
    25.10.1993
    3042
    1.69
    31.0
    14.0
    WATER BASED
    27.10.1993
    3059
    1.68
    35.0
    15.0
    WATER BASED
    28.10.1993
    3085
    1.68
    35.0
    15.0
    WATER BASED
    01.11.1993
    3090
    1.69
    37.0
    15.0
    WATER BASED
    01.11.1993
    3123
    1.69
    35.0
    16.0
    WATER BASED
    01.11.1993
    3130
    1.69
    35.0
    15.0
    WATER BASED
    01.11.1993
    3147
    1.70
    33.0
    14.0
    WATER BASED
    02.11.1993
    3270
    1.68
    37.0
    16.0
    WATER BASED
    03.11.1993
    3281
    1.68
    38.0
    16.0
    WATER BASED
    04.11.1993
    3281
    1.68
    38.0
    16.0
    WATER BASED
    08.11.1993
    3409
    1.66
    32.0
    7.5
    WATER BASED
    01.12.1993
    3470
    1.66
    25.0
    7.0
    WATER BASED
    06.12.1993
    3470
    1.66
    25.0
    7.0
    WATER BASED
    06.12.1993
    3470
    1.66
    25.0
    7.0
    WATER BASED
    06.12.1993
    3470
    1.60
    19.0
    7.0
    WATER BASED
    07.12.1993
    3470
    1.68
    33.0
    13.0
    WATER BASED
    08.11.1993
    3470
    1.66
    29.0
    7.5
    WATER BASED
    22.11.1993
    3470
    1.66
    27.0
    5.5
    WATER BASED
    02.12.1993
    3470
    1.66
    26.0
    6.0
    WATER BASED
    06.12.1993
    3470
    1.66
    25.0
    6.5
    WATER BASED
    06.12.1993
    3470
    1.68
    34.0
    14.0
    WATER BASED
    08.11.1993
    3470
    1.68
    33.0
    14.0
    WATER BASED
    08.11.1993
    3470
    1.68
    33.0
    13.0
    WATER BASED
    09.11.1993
    3470
    1.68
    38.0
    13.0
    WATER BASED
    11.11.1993
    3470
    1.68
    35.0
    13.0
    WATER BASED
    12.11.1993
    3470
    1.68
    37.0
    14.0
    WATER BASED
    12.11.1993
    3470
    1.68
    367.0
    17.0
    WATER BASED
    16.11.1993
    3470
    1.68
    367.0
    17.0
    WATER BASED
    16.11.1993
    3470
    1.66
    27.0
    8.0
    WATER BASED
    16.11.1993
    3470
    1.66
    28.0
    8.5
    WATER BASED
    16.11.1993
    3470
    1.66
    28.0
    8.5
    WATER BASED
    17.11.1993
    3470
    1.66
    28.0
    7.5
    WATER BASED
    18.11.1993
    3470
    1.66
    28.0
    7.5
    WATER BASED
    19.11.1993
    3470
    1.65
    29.0
    7.0
    WATER BASED
    22.11.1993
    3470
    1.66
    29.0
    7.0
    WATER BASED
    22.11.1993
    3470
    1.66
    30.0
    6.0
    WATER BASED
    23.11.1993
    3470
    1.66
    29.0
    7.0
    WATER BASED
    24.11.1993
    3470
    1.66
    29.0
    7.0
    WATER BASED
    25.11.1993
    3470
    1.66
    29.0
    7.0
    WATER BASED
    26.11.1993
    3470
    1.66
    29.0
    7.0
    WATER BASED
    30.11.1993
    3470
    1.66
    25.0
    7.5
    WATER BASED
    30.11.1993

  • 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