Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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15.07.2024 - 01:28
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35/11-8 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.
    35/11-8 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).
    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.
    35/11-8
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    MN 9201- INLINE 4287 & CROSSLINE 1277
    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.
    841-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.
    70
    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,
    03.03.1996
    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.
    11.05.1996
    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.
    11.05.1998
    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.
    15.06.2005
    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.
    INTRA HEATHER 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.
    361.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3624.0
    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).
    3355.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    33
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    128
    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° 5' 25.53'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    3° 32' 14.85'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6773139.14
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    528987.44
    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.
    2772
  • Wellbore history

    General
    Well 35/11-8 S is located ca 15 km due north of the Troll Field. It was designed to test the hydrocarbon potential in the H-structure located in a down-faulted position west of the F/C complex where oil and gas was discovered in the wells 35/11-4 and -7. The main targets were the Brent Group and the Sognefjord Formation equivalent. Possible secondary targets were seen in Intra Draupne sandstone and a mound feature in the Paleocene sequence.
    Operations and results
    Wildcat well 35/11-8 S was spudded with the semi-submersible installation Treasure Saga on 3 March 1996 and drilled to TD at 3624 m (3355 m TVD RKB) m in the Early Jurassic Drake Formation. The well was drilled vertically in the top hole, starting to build angle below the 30" casing shoe at 447 m. From 950 m to 2250 m the deviation was kept at 31 ± 2°, from which point the inclination was gradually reduced towards a more vertical path. After the testing phase, operations were interrupted for some three days by an industrial strike. Operations went without significant technical problems. The well was drilled with spud mud down to 1233 m and with KCl/polymer mud from 1233 m to TD.
    The Paleocene mound feature proved to consists of 66 m of water bearing sand with weak shows in the uppermost part.
    The prognosed lead related to the high amplitude Intra Draupne reflector corresponded to the Late Jurassic source rock. A thin sandstone at the base of the Sognefjord Formation was water filled with weak shows. Oil and gas was discovered in a 115 m thick Late Jurassic turbiditic sandstone unit at 2860 m. The sequence could not be correlated with the Sognefjord Formation in the neighbouring wells and is classified as an Intra Heather Sandstone unit. From 2860 to 2881 m 20.7 m net pay gas reservoir showed a gas saturation of 89 % and the average porosity was calculated to 21.9 %. A 40.1 m net pay oil zone was calculated for the interval between 2881m and 2938 m. Average porosity for this interval is 22.1 % and the oil saturation is 80.0 %. MDT pressure measurements gave a gas-oil contact at 2881 m (2600 m TVD MSL) and an oil-water contact at 2938 m (2654 m TVD MSL). Low saturation of residual hydrocarbons were observed in intervals below the oil-water contact. The Brent Group was encountered at 3376.5 m and was water bearing. A trace oil show was however recorded at 3467 m in the Etive Formation. The MDT pressure measurements failed to define a water gradient due to poor reservoir quality. Four cores were taken in the Intra Heather Sandstone unit, covering the gas zone, the oil zone, and parts of the water zone. An MDT water sample was taken at 2818 m in the Sognefjord Formation. MDT water samples were taken also in the Brent Group.
    The well was permanently abandoned on 11 May 1996 as an oil and gas discovery.
    Testing
    Three drill stem tests were conducted in the Intra Heather Sandstone unit. DST 1 tested the interval 2924 m to 2931 m, DST 1B tested the intervals 2924 m to 2931 m and 2910 m to 2920 m, and DST 2 tested the interval 2885 m to 2892 m. All three tests produced 0.85 g/cm3 (35 deg API) oil with GOR in the range 95 to 113 Sm3/Sm3.
  • 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]
    1240.00
    3625.00
  • 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
    2866.0
    2883.7
    [m ]
    2
    2884.0
    2911.5
    [m ]
    3
    2911.5
    2936.2
    [m ]
    4
    2938.0
    2964.0
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    95.9
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES
  • Core photos

    Core photos
    Core photo at depth: 2866-2871m
    Core photo at depth: 2871-2876m
    Core photo at depth: 2876-2881m
    Core photo at depth: 2881-2883m
    Core photo at depth: 2884-2889m
    2866-2871m
    2871-2876m
    2876-2881m
    2881-2883m
    2884-2889m
    Core photo at depth: 2889-2894m
    Core photo at depth: 2894-2899m
    Core photo at depth: 2899-2904m
    Core photo at depth: 2904-2909m
    Core photo at depth: 2909-2911m
    2889-2894m
    2894-2899m
    2899-2904m
    2904-2909m
    2909-2911m
    Core photo at depth: 2911-2916m
    Core photo at depth: 2916-2921m
    Core photo at depth: 2921-2926m
    Core photo at depth: 2926-2931m
    Core photo at depth: 2931-2936m
    2911-2916m
    2916-2921m
    2921-2926m
    2926-2931m
    2931-2936m
    Core photo at depth: 2936-2936m
    Core photo at depth: 2938-2943m
    Core photo at depth: 2943-2948m
    Core photo at depth: 2948-2953m
    Core photo at depth: 2953-2958m
    2936-2936m
    2938-2943m
    2943-2948m
    2948-2953m
    2953-2958m
    Core photo at depth: 2958-2963m
    Core photo at depth: 2963-2964m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    2958-2963m
    2963-2964m
  • Palynological slides at the Norwegian Offshore Directorate

    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1240.0
    [m]
    DC
    RRI
    1260.0
    [m]
    DC
    RRI
    1280.0
    [m]
    DC
    RRI
    1300.0
    [m]
    DC
    RRI
    1320.0
    [m]
    DC
    RRI
    1340.0
    [m]
    DC
    RRI
    1360.0
    [m]
    DC
    RRI
    1380.0
    [m]
    DC
    RRI
    1400.0
    [m]
    DC
    RRI
    1420.0
    [m]
    DC
    RRI
    1440.0
    [m]
    DC
    RRI
    1460.0
    [m]
    DC
    RRI
    1480.0
    [m]
    DC
    RRI
    1500.0
    [m]
    DC
    RRI
    1520.0
    [m]
    DC
    RRI
    1540.0
    [m]
    DC
    RRI
    1560.0
    [m]
    DC
    RRI
    1580.0
    [m]
    DC
    RRI
    1600.0
    [m]
    DC
    RRI
    1620.0
    [m]
    DC
    RRI
    1640.0
    [m]
    DC
    RRI
    1650.0
    [m]
    DC
    RRI
    1660.0
    [m]
    DC
    RRI
    1670.0
    [m]
    DC
    RRI
    1680.0
    [m]
    DC
    RRI
    1690.0
    [m]
    DC
    RRI
    1700.0
    [m]
    DC
    RRI
    1710.0
    [m]
    DC
    RRI
    1720.0
    [m]
    DC
    RRI
    1730.0
    [m]
    DC
    RRI
    1740.0
    [m]
    DC
    RRI
    1750.0
    [m]
    DC
    RRI
    1760.0
    [m]
    DC
    RRI
    1770.0
    [m]
    DC
    RRI
    1785.0
    [m]
    SWC
    RRI
    1792.0
    [m]
    SWC
    RRI
    1800.0
    [m]
    DC
    RRI
    1810.0
    [m]
    DC
    RRI
    1820.0
    [m]
    DC
    RRI
    1826.0
    [m]
    SWC
    RRI
    1840.0
    [m]
    DC
    RRI
    1850.0
    [m]
    DC
    RRI
    1860.0
    [m]
    DC
    RRI
    1880.0
    [m]
    DC
    RRI
    1888.0
    [m]
    SWC
    RRI
    1905.0
    [m]
    SWC
    RRI
    1920.0
    [m]
    DC
    RRI
    1930.0
    [m]
    DC
    RRI
    1940.0
    [m]
    DC
    RRI
    1950.0
    [m]
    DC
    RRI
    1960.0
    [m]
    DC
    RRI
    1970.0
    [m]
    DC
    RRI
    1980.0
    [m]
    DC
    RRI
    1990.0
    [m]
    DC
    RRI
    2000.0
    [m]
    DC
    RRI
    2010.0
    [m]
    DC
    RRI
    2020.0
    [m]
    DC
    RRI
    2030.0
    [m]
    DC
    RRI
    2040.0
    [m]
    DC
    RRI
    2050.0
    [m]
    SWC
    RRI
    2060.0
    [m]
    DC
    RRI
    2070.0
    [m]
    DC
    RRI
    2080.0
    [m]
    DC
    RRI
    2089.0
    [m]
    SWC
    RRI
    2101.0
    [m]
    DC
    RRI
    2110.0
    [m]
    DC
    RRI
    2120.0
    [m]
    DC
    RRI
    2130.0
    [m]
    DC
    RRI
    2150.0
    [m]
    DC
    RRI
    2190.0
    [m]
    DC
    RRI
    2210.0
    [m]
    DC
    RRI
    2230.0
    [m]
    DC
    RRI
    2250.0
    [m]
    DC
    RRI
    2270.0
    [m]
    DC
    RRI
    2290.0
    [m]
    DC
    RRI
    2310.0
    [m]
    DC
    RRI
    2330.0
    [m]
    DC
    RRI
    2350.0
    [m]
    DC
    RRI
    2370.0
    [m]
    DC
    RRI
    2390.0
    [m]
    DC
    RRI
    2410.0
    [m]
    DC
    RRI
    2430.0
    [m]
    DC
    RRI
    2450.0
    [m]
    DC
    RRI
    2470.0
    [m]
    DC
    RRI
    2510.0
    [m]
    DC
    RRI
    2530.0
    [m]
    DC
    RRI
    2550.0
    [m]
    DC
    RRI
    2570.0
    [m]
    DC
    RRI
    2580.0
    [m]
    DC
    RRI
    2590.0
    [m]
    DC
    RRI
    2600.0
    [m]
    DC
    RRI
    2610.0
    [m]
    DC
    RRI
    2620.0
    [m]
    DC
    RRI
    2630.0
    [m]
    DC
    RRI
    2640.0
    [m]
    DC
    RRI
    2650.0
    [m]
    DC
    RRI
    2660.0
    [m]
    SWC
    RRI
    2670.0
    [m]
    SWC
    RRI
    2680.0
    [m]
    DC
    RRI
    2690.0
    [m]
    DC
    RRI
    2700.0
    [m]
    DC
    RRI
    2710.0
    [m]
    DC
    RRI
    2720.0
    [m]
    DC
    RRI
    2730.0
    [m]
    DC
    RRI
    2740.0
    [m]
    DC
    RRI
    2754.0
    [m]
    SWC
    RRI
    2760.0
    [m]
    DC
    RRI
    2770.0
    [m]
    DC
    RRI
    2780.0
    [m]
    DC
    RRI
    2787.0
    [m]
    SWC
    RRI
    2800.0
    [m]
    DC
    RRI
    2810.0
    [m]
    DC
    RRI
    2820.0
    [m]
    DC
    RRI
    2830.0
    [m]
    DC
    RRI
    2840.0
    [m]
    DC
    RRI
    2852.0
    [m]
    DC
    RRI
    2862.0
    [m]
    DC
    RRI
    2872.0
    [m]
    DC
    RRI
    2878.0
    [m]
    C
    RRI
    2880.0
    [m]
    C
    RRI
    2894.0
    [m]
    C
    RRI
    2899.0
    [m]
    C
    RRI
    2904.0
    [m]
    DC
    RRI
    2907.0
    [m]
    C
    RRI
    2918.0
    [m]
    C
    RRI
    2930.0
    [m]
    C
    RRI
    2933.0
    [m]
    C
    RRI
    2935.0
    [m]
    C
    RRI
    2950.0
    [m]
    C
    RRI
    2962.0
    [m]
    C
    RRI
    2970.0
    [m]
    DC
    RRI
    2980.0
    [m]
    DC
    RRI
    2990.0
    [m]
    SWC
    RRI
    2997.0
    [m]
    SWC
    RRI
    3010.0
    [m]
    DC
    RRI
    3020.0
    [m]
    DC
    RRI
    3030.0
    [m]
    DC
    RRI
    3038.0
    [m]
    SWC
    SWC
    3050.0
    [m]
    DC
    RRI
    3060.0
    [m]
    DC
    RRI
    3070.0
    [m]
    DC
    RRI
    3080.0
    [m]
    DC
    RRI
    3090.0
    [m]
    DC
    RRI
    3100.0
    [m]
    DC
    RRI
    3110.0
    [m]
    DC
    RRI
    3120.0
    [m]
    DC
    RRI
    3130.0
    [m]
    DC
    RRI
    3135.0
    [m]
    SWC
    RRI
    3140.0
    [m]
    DC
    RRI
    3150.0
    [m]
    DC
    RRI
    3160.0
    [m]
    DC
    RRI
    3170.0
    [m]
    DC
    RRI
    3180.0
    [m]
    DC
    RRI
    3190.0
    [m]
    DC
    RRI
    3200.0
    [m]
    DC
    RRI
    3210.0
    [m]
    DC
    RRI
    3222.0
    [m]
    DC
    RRI
    3250.0
    [m]
    DC
    RRI
    3260.0
    [m]
    DC
    RRI
    3270.0
    [m]
    DC
    RRI
    3280.0
    [m]
    DC
    RRI
    3290.0
    [m]
    DC
    RRI
    3300.0
    [m]
    DC
    RRI
    3310.0
    [m]
    DC
    RRI
    3320.0
    [m]
    DC
    RRI
    3330.0
    [m]
    DC
    RRI
    3340.0
    [m]
    DC
    RRI
    3350.0
    [m]
    DC
    RRI
    3360.0
    [m]
    DC
    RRI
    3370.0
    [m]
    DC
    RRI
    3380.0
    [m]
    DC
    RRI
    3390.0
    [m]
    DC
    RRI
    3400.0
    [m]
    DC
    RRI
    3410.0
    [m]
    DC
    RRI
    3420.0
    [m]
    DC
    RRI
    3430.0
    [m]
    DC
    RRI
    3440.0
    [m]
    DC
    RRI
    3450.0
    [m]
    DC
    RRI
    3460.0
    [m]
    DC
    RRI
    3470.0
    [m]
    DC
    RRI
    3480.0
    [m]
    DC
    RRI
    3503.0
    [m]
    SWC
    RRI
    3510.0
    [m]
    DC
    RRI
    3520.0
    [m]
    DC
    RRI
    3535.0
    [m]
    DC
    RRI
    3545.0
    [m]
    SWC
    RRI
    3555.0
    [m]
    DC
    RRI
    3565.0
    [m]
    DC
    RRI
    3575.0
    [m]
    DC
    RRI
    3595.0
    [m]
    DC
    RRI
    3605.0
    [m]
    DC
    RRI
  • 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
    TEST 1B
    2931.00
    2885.00
    21.04.1996 - 00:00
    YES
    DST
    TEST2
    2892.00
    2885.00
    27.04.1996 - 13:47
    YES
  • Lithostratigraphy

  • Composite logs

    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.58
  • 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
    18.64
  • Drill stem tests (DST)

    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    2924
    2931
    19.1
    2.0
    2910
    2920
    19.1
    3.0
    2886
    2901
    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
    26.000
    21.000
    27.000
    104
    2.0
    26.000
    24.000
    27.000
    105
    3.0
    26.000
    25.000
    27.000
    103
    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
    700
    79000
    0.850
    0.720
    112
    2.0
    860
    82000
    0.850
    0.690
    95
    3.0
    520
    58000
    0.850
    0.706
    112
  • Logs

    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL VBDL USIT GR CCL AMS
    1650
    3227
    CST GR
    1785
    3135
    CST GR
    2588
    3462
    DLL MSFL LSS LDL CNL GR AMS SP
    1195
    3629
    FMS NGT
    1703
    3110
    MDT GR
    1872
    2975
    MDT GR
    2896
    2930
    MDT GR
    3380
    3483
    MDT GR
    3381
    3490
    MWD
    387
    3624
    VSP GR
    1420
    3600
  • 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
    447.0
    36
    450.0
    0.00
    LOT
    SURF.COND.
    13 3/8
    1220.0
    17 1/2
    1233.0
    0.00
    LOT
    INTERM.
    9 5/8
    3232.0
    12 1/4
    3242.0
    0.00
    LOT
    OPEN HOLE
    3624.0
    8 1/2
    3624.0
    0.00
    LOT
  • Drilling mud

    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    449
    1.03
    WATER BASED
    1233
    1.30
    16.0
    WATER BASED
    1787
    1.30
    24.0
    WATER BASED
    2224
    1.30
    28.0
    WATER BASED
    2650
    1.12
    WATER BASED
    2907
    1.12
    14.0
    WATER BASED
    3085
    1.12
    16.0
    WATER BASED
    3242
    1.30
    23.0
    WATER BASED
    3263
    1.31
    22.0
    WATER BASED
    3624
    1.31
    22.0
    WATER 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
    0.24