Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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sodir.no          Norsk
22.12.2024 - 01:25
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34/10-38 S

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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.
    34/10-38 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.
    34/10-38
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    ST 9207 rekke 1520 & kolonne 920
    Production licence
    Official designation of the production licence the wellbore was drilled or planned to be drilled from ( well head posistion).
    Drilling operator
    Name of the licensee starting the drilling operation on behalf of the active production license (well head position). This will usually equal the operator of the production license.
    Den norske stats oljeselskap a.s
    Drill permit
    The drilling permit number together with the version of the drilling permit as stated in the drilling permit granted by the Norwegian Offshore Directorate.
    805-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.
    55
    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,
    05.04.1995
    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.
    29.05.1995
    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.
    29.05.1997
    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.
    06.01.2014
    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/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.
    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.
    COOK FM
    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.
    EARLY JURASSIC
    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.
    STATFJORD GP
    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.
    137.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3940.0
    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).
    3393.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    58.2
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    124
    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° 4' 23.27'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 1' 37.18'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6771483.91
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    447493.92
    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.
    2517

  • Wellbore history
    General
    Well 34/10-38 S was drilled to appraise the 34/10-17 Rimfaks Discovery south-west of the Gullfaks field in the North Sea. The primary objective was to test the hydrocarbon potential of the Middle Jurassic Brent Group in Segment 1 of the structure. Secondary objective was to test the hydrocarbon potential of the Early Jurassic Statfjord Group in Segment 2.
    Operations and results
    Appraisal well 34/10-38 S was spudded with the semi-submersible installation Deepsea Bergen on 5 April 1995 and drilled to TD at 3940 m (3393 m TVD) in the Late Triassic Lunde Formation. Drilling went forth without significant problem. Lost time was mostly related to logging problems in the 8 1/2" section. The well was drilled with bentonite and CMC/EHV down to 670 m, with ANCO 2000 mud from 670 m to 2075 m and with oil based Safemul PE/SE mud from 2075 m to TD.
    The results of the well differed from the geological prognosis. The Viking Group and most of the Brent Group in segment 2 was eroded and the remaining of the Brent Group was heavily faulted and fractured. Top Brent Group came in at 3021 m (2653.8 m TVD). Top Statfjord Group was penetrated at 3451 m (2995.2 m TVD), about 200 m shallower than prognosed. The Brent Group, the Cook Formation and the Statfjord Group proved to be hydrocarbon bearing. Pressure samples and log analysis proved an oil-water contact at 3585.6 m (3103.5 m TVD) in the Statfjord Group. Shows and log analysis indicated, however, oil with low saturation down to approx, 3658 m.
    Nine cores were cut in the well. The first core was cut from 3140 to 3159 m but recovered only a 10 cm piece. Cores 2 to 9 were cut in the Statfjord Group from 3465 m to 3631 m with generally good recovery. The core depths were from 0 to 3 m shallower than the log depths. FMT fluid samples were taken in the Brent Group at 3039.4 m (gas and condensate), and in the Statfjord Group at 3456.5 m (oil and gas), 3567.5 m (oil and gas), 3643 m (oil and water), and 3812 m (water). The oil in the sample from 3643 is believed to be residual oil mobilised by the oil base in the mud.
    The well was permanently abandoned on 29 May 1995 as an oil and gas appraisal well.
    Testing
    Two intervals were tested in a comingled drill stem test from below and above the OWC in the Statfjord Group.
    The main objective for DST1 A from 3637 to 3646 m was to test the type of moveable fluid below the OWC where shows, a low hydrocarbon saturation and oil in an FMT sample indicated presence of oil. The result of the test was water at a rate of 23 Sm3/day through a 64/64" choke. Only traces of oil were produced. The flowing bottom hole temperature was 113.2 deg C.
    DST1 B tested the interval 3561 to 3570 m in the oil zone in addition to 3637 to 3646 m. DST1 B produced 858 Sm3 oil and 199056 Sm3 gas /day through a 36/64" choke. No water was produced. The GOR was 232 Sm3/Sm3, the oil density was 0.846 g/cm3, and the gas gravity was 0.807 (air = 1). The flowing bottom hole temperature was 115.4 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]
    680.00
    3940.00

  • 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
    3140.0
    3140.1
    [m ]
    2
    3465.0
    3482.4
    [m ]
    3
    3482.4
    3484.1
    [m ]
    4
    3485.0
    3513.2
    [m ]
    5
    3513.4
    3535.4
    [m ]
    6
    3537.0
    3565.5
    [m ]
    7
    3565.5
    3595.8
    [m ]
    8
    3598.0
    3611.8
    [m ]
    9
    3613.0
    3631.3
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    160.2
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    960.0
    [m]
    DC
    GEOSTR
    980.0
    [m]
    DC
    GEOSTR
    1010.0
    [m]
    DC
    GEOSTR
    1040.0
    [m]
    DC
    GEOSTR
    1070.0
    [m]
    DC
    GEOSTR
    1100.0
    [m]
    DC
    GEOSTR
    1130.0
    [m]
    DC
    GEOSTR
    1160.0
    [m]
    DC
    GEOSTR
    1180.0
    [m]
    DC
    GEOSTR
    1220.0
    [m]
    DC
    GEOSTR
    1250.0
    [m]
    DC
    GEOSTR
    1280.0
    [m]
    DC
    GEOSTR
    1310.0
    [m]
    DC
    GEOSTR
    1340.0
    [m]
    DC
    GEOSTR
    1370.0
    [m]
    DC
    GEOSTR
    1400.0
    [m]
    DC
    GEOSTR
    1420.0
    [m]
    DC
    GEOSTR
    1470.0
    [m]
    DC
    GEOSTR
    1490.0
    [m]
    DC
    GEOSTR
    1520.0
    [m]
    DC
    GEOSTR
    1550.0
    [m]
    DC
    GEOSTR
    1580.0
    [m]
    DC
    GEOSTR
    1610.0
    [m]
    DC
    GEOSTR
    1640.0
    [m]
    DC
    GEOSTR
    1670.0
    [m]
    DC
    GEOSTR
    1700.0
    [m]
    DC
    GEOSTR
    1730.0
    [m]
    DC
    GEOSTR
    1760.0
    [m]
    DC
    GEOSTR
    1780.0
    [m]
    DC
    GEOSTR
    1790.0
    [m]
    DC
    GEOSTR
    1820.0
    [m]
    DC
    GEOSTR
    1850.0
    [m]
    DC
    GEOSTR
    1880.0
    [m]
    DC
    GEOSTR
    1910.0
    [m]
    DC
    GEOSTR
    1940.0
    [m]
    DC
    GEOSTR
    1970.0
    [m]
    DC
    GEOSTR
    1980.0
    [m]
    DC
    GEOSTR
    1990.0
    [m]
    DC
    GEOSTR
    2000.0
    [m]
    DC
    GEOSTR
    2030.0
    [m]
    DC
    GEOSTR
    2060.0
    [m]
    DC
    GEOSTR
    2090.0
    [m]
    DC
    GEOSTR
    2120.0
    [m]
    DC
    GEOSTR
    2150.0
    [m]
    DC
    GEOSTR
    2180.0
    [m]
    DC
    GEOSTR
    2210.0
    [m]
    DC
    GEOSTR
    2240.0
    [m]
    DC
    GEOSTR
    2270.0
    [m]
    DC
    GEOSTR
    2300.0
    [m]
    DC
    GEOSTR
    2330.0
    [m]
    DC
    GEOSTR
    2360.0
    [m]
    DC
    GEOSTR
    2390.0
    [m]
    DC
    GEOSTR
    2420.0
    [m]
    DC
    GEOSTR
    2450.0
    [m]
    DC
    GEOSTR
    2480.0
    [m]
    DC
    GEOSTR
    2500.0
    [m]
    DC
    GEOSTR
    2540.0
    [m]
    DC
    GEOSTR
    2570.0
    [m]
    DC
    GEOSTR
    2600.0
    [m]
    DC
    GEOSTR
    2630.0
    [m]
    DC
    GEOSTR
    2660.0
    [m]
    DC
    GEOSTR
    2696.0
    [m]
    DC
    GEOSTR
    2720.0
    [m]
    DC
    GEOSTR
    2750.0
    [m]
    DC
    GEOSTR
    2780.0
    [m]
    DC
    GEOSTR
    2810.0
    [m]
    DC
    GEOSTR
    2840.0
    [m]
    DC
    GEOSTR
    2870.0
    [m]
    DC
    GEOSTR
    2900.0
    [m]
    DC
    GEOSTR
    2930.0
    [m]
    DC
    GEOSTR
    2961.0
    [m]
    DC
    GEOSTR
    2991.0
    [m]
    DC
    GEOSTR
    3000.0
    [m]
    DC
    GEOSTR
    3010.0
    [m]
    SWC
    WESTL
    3012.0
    [m]
    DC
    GEOSTR
    3017.0
    [m]
    SWC
    WESTL
    3021.0
    [m]
    DC
    GEOSTR
    3022.0
    [m]
    SWC
    WESTL
    3030.0
    [m]
    SWC
    WESTL
    3045.0
    [m]
    SWC
    WESTL
    3048.0
    [m]
    SWC
    WESTL
    3053.0
    [m]
    SWC
    WESTL
    3062.0
    [m]
    SWC
    WESTL
    3072.0
    [m]
    DC
    GEOSTR
    3081.0
    [m]
    DC
    GEOSTR
    3090.0
    [m]
    DC
    GEOSTR
    3099.0
    [m]
    DC
    GEOSTR
    3107.0
    [m]
    SWC
    WESTL
    3113.0
    [m]
    SWC
    WESTL
    3121.0
    [m]
    SWC
    WESTL
    3129.0
    [m]
    DC
    GEOSTR
    3134.0
    [m]
    SWC
    WESTL
    3140.0
    [m]
    C
    WESTL
    3141.0
    [m]
    SWC
    WESTL
    3146.0
    [m]
    SWC
    WESTL
    3155.0
    [m]
    SWC
    WESTL
    3165.0
    [m]
    DC
    GEOSTR
    3173.0
    [m]
    SWC
    WESTL
    3186.0
    [m]
    DC
    GEOSTR
    3198.0
    [m]
    DC
    GEOSTR
    3212.0
    [m]
    SWC
    WESTL
    3222.0
    [m]
    DC
    GEOSTR
    3234.0
    [m]
    DC
    GEOSTR
    3249.0
    [m]
    DC
    GEOSTR
    3263.0
    [m]
    SWC
    WESTL
    3267.0
    [m]
    DC
    GEOSTR
    3270.0
    [m]
    SWC
    WESTL
    3285.0
    [m]
    DC
    GEOSTR
    3297.0
    [m]
    DC
    GEOSTR
    3312.0
    [m]
    DC
    GEOSTR
    3327.0
    [m]
    DC
    GEOSTR
    3342.0
    [m]
    DC
    GEOSTR
    3356.0
    [m]
    SWC
    WESTL
    3366.0
    [m]
    DC
    GEOSTR
    3381.0
    [m]
    DC
    GEOSTR
    3387.0
    [m]
    DC
    GEOSTR
    3396.0
    [m]
    DC
    GEOSTR
    3402.0
    [m]
    DC
    GEOSTR
    3408.0
    [m]
    DC
    GEOSTR
    3417.0
    [m]
    DC
    GEOSTR
    3423.0
    [m]
    DC
    GEOSTR
    3430.0
    [m]
    SWC
    WESTL
    3438.0
    [m]
    DC
    GEOSTR
    3444.0
    [m]
    DC
    GEOSTR
    3450.0
    [m]
    DC
    GEOSTR
    3450.0
    [m]
    SWC
    WESTL
    3483.0
    [m]
    C
    WESTL
    3489.0
    [m]
    C
    WESTL
    3494.0
    [m]
    C
    WESTL
    3499.0
    [m]
    C
    WESTL
    3501.0
    [m]
    C
    WESTL
    3513.0
    [m]
    C
    WESTL
    3517.0
    [m]
    C
    WESTL
    3521.0
    [m]
    C
    WESTL
    3526.0
    [m]
    C
    WESTL
    3537.0
    [m]
    C
    WESTL
    3543.0
    [m]
    C
    WESTL
    3549.0
    [m]
    C
    WESTL
    3557.0
    [m]
    C
    WESTL
    3569.0
    [m]
    C
    WESTL
    3573.0
    [m]
    C
    WESTL
    3579.0
    [m]
    C
    WESTL
    3583.0
    [m]
    C
    WESTL
    3588.0
    [m]
    C
    WESTL
    3594.0
    [m]
    C
    WESTL
    3600.0
    [m]
    C
    WESTL
    3609.0
    [m]
    C
    WESTL
    3613.0
    [m]
    C
    WESTL
    3620.0
    [m]
    C
    WESTL
    3646.0
    [m]
    DC
    GEOSTR
    3655.0
    [m]
    DC
    GEOSTR
    3676.0
    [m]
    DC
    GEOSTR
    3694.0
    [m]
    DC
    GEOSTR
    3715.0
    [m]
    DC
    GEOSTR
    3721.0
    [m]
    DC
    GEOSTR
    3733.0
    [m]
    DC
    GEOSTR
    3745.0
    [m]
    DC
    GEOSTR
    3757.0
    [m]
    DC
    GEOSTR
    3772.0
    [m]
    DC
    GEOSTR
    3784.0
    [m]
    DC
    GEOSTR
    3796.0
    [m]
    DC
    GEOSTR
    3808.0
    [m]
    DC
    GEOSTR
    3820.0
    [m]
    DC
    GEOSTR
    3832.0
    [m]
    DC
    GEOSTR
    3844.0
    [m]
    DC
    GEOSTR
    3850.0
    [m]
    DC
    GEOSTR
    3862.0
    [m]
    DC
    GEOSTR
    3874.0
    [m]
    DC
    GEOSTR
    3883.0
    [m]
    DC
    GEOSTR
    3904.0
    [m]
    DC
    GEOSTR
    3916.0
    [m]
    DC
    GEOSTR
    3928.0
    [m]
    DC
    GEOSTR
    3940.0
    [m]
    DC
    GEOSTR

  • 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
    TEST1B
    0.00
    0.00
    23.05.1995 - 02:35
    YES

  • Lithostratigraphy

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.41
    pdf
    11.10

  • 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
    16.94

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    3637
    3646
    25.4
    2.0
    3561
    3570
    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
    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
    1
    0.875
    2.0
    858
    199056
    0.846
    0.807
    232

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CIBL GR TTRM
    2989
    3160
    DIPL MAC CN ZDL DSL TTRM
    2060
    3847
    FMT QDYNE GR CHR
    3039
    3039
    FMT QDYNE GR CHT
    3022
    3864
    FMT QDYNE GR CHT
    3113
    3465
    FMT QDYNE GR CHT
    3567
    3567
    FMT QDYNE GR CHT
    3643
    3643
    FMT QDYNE GR CHT
    3812
    3812
    HRDIP GR
    2965
    3940
    MWD - DPR
    2075
    3940
    MWD - RGD
    222
    2075
    SWC GR
    3009
    3720
    SWC GR
    3863
    3927
    VSP
    1805
    3930

  • 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
    219.0
    36
    224.0
    0.00
    LOT
    SURF.COND.
    20
    659.0
    26
    670.0
    1.57
    LOT
    INTERM.
    13 3/8
    2064.0
    17 1/2
    2075.0
    2.07
    LOT
    INTERM.
    7
    3720.0
    8 1/2
    3940.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    224
    1.03
    water based
    1295
    1.26
    20.0
    water based
    2075
    1.25
    water based
    2673
    1.60
    42.0
    oil based
    3021
    1.60
    54.0
    oil based
    3030
    1.60
    55.0
    oil based
    3159
    1.60
    50.0
    oil based
    3374
    1.60
    57.0
    oil based
    3565
    1.43
    51.0
    oil based
    3613
    1.60
    54.0
    oil based
    3726
    1.60
    56.0
    oil based
    3886
    1.60
    52.0
    oil based
    3940
    1.60
    52.0
    oil based

  • Pressure plots
    Pressure plots
    The pore pressure data is sourced from well logs if no other source is specified. In some wells where pore pressure logs do not exist, information from Drill stem tests and kicks have been used. The data has been reported to the NPD, and further processed and quality controlled by IHS Markit.
    Pressure plots
    Document name
    Document format
    Document size [MB]
    pdf
    0.23