Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
22.12.2024 - 01:25
Time of last synchronization with Norwegian Offshore Directorate's internal systems

30/9-10

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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.
    30/9-10
    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.
    30/9-10
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    NH 8502-332 X-OVER NH 8502-430
    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.
    646-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.
    53
    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,
    31.07.1990
    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.
    21.09.1990
    Plugged and abondon date
    Date when the P&A-operations of the wellbore was finished, as reported by the operator to the Norwegian Offshore Directorate throught DDRS (Daily Drilling Reporting System). Only applied once pr. wellhead/surface location.
    11.05.2000
    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.
    21.09.1992
    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.
    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.
    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 DRAUPNE FM SS
    2nd level with HC, age
    Age of lithostratigraphic unit, 2nd level, where hydrocarbons were encountered. Examples of legal values: CRETACEOUS, EARLY CRETACEOUS, LATE JURASSIC, EOCENE.
    MIDDLE JURASSIC
    2nd level with HC, formation
    Name of lithostartigraphic unit, 2nd level, where hydrocarbons were encountered. Shown only for released wells. Examples of legal values: BASEMENT, COOK FM, EKOFISK FM, HEIMDAL FM, SANDNES FM, SOGNEFJORD FM, TARBERT FM, BRENT GP.
    TARBERT FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    25.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    99.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3649.0
    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).
    3642.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    11
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    131
    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.
    STATFJORD GP
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    60° 23' 23.2'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 47' 13.16'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6694997.50
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    488258.20
    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.
    1514

  • Wellbore history
    General
    Well 30/9-10 was drilled in the Omega South segment on the Oseberg Fault Block in the North Sea. The primary objective was to test the hydrocarbon potential in the Tarbert Formation. Secondary objectives were to test the Cook Formation and the Statfjord Group.
    Operations and results
    Wildcat well was spudded with the semi-submersible installation Vildkat on 31 July 1990 and drilled to TD at 3649 m in the Early Jurassic Statfjord Group. An 8 1/2" pilot hole was drilled from 210 to 350 m to check a possible shallow gas zone at 329 m. No gas was encountered. No significant problem was encountered in the operations. The well was drilled with spud mud down to 1059 m and with KCl/polymer mud from 1059 m to TD.
    The Draupne Formation was encountered at 2717 m and Intra Draupne Formation sandstone was penetrated from 2756 m to top Tarbert Formation at 2783 m. The Draupne Formation sandstone and the Upper Tarbert Formation were found to be oil bearing from 2756 - 2833 m. Poor to moderate oil shows continued down to 2858 m. No oil shows were recorded below this depth or above top Draupne Formation. The Middle Tarbert is poor or tight, and non-moveable hydrocarbons were present in the Lower Tarbert, which are interpreted from core analysis to be residual oil. The net pay was determined to be 55 m, with an average water saturation of 36.4% and average porosity of 17.5%. RFT data defines an oil gradient through Draupne and Upper Tarbert sandstones, which intersects with the Lower Tarbert water gradient at 2833 m in the Middle Tarbert. However, it is uncertain whether the oil gradient in the Upper Tarbert and the water gradient of the Lower Tarbert belong to the same pressure system. Consequently an oil-water contact was not proven in the well. The Cook Formation and the Statfjord Group were found water bearing with no shows.
    Three cores were cut from 2725 m to 2732.5 m in the Draupne Formation. Poor recovery was obtained in these cores. Another four cores were cut from 2747 m in the Draupne Formation, through Intra Draupne Formation sandstone, the Tarbert Formation, and to 2894.5 m in the Ness Formation. Good recovery was obtained in these cores. RFT fluid samples were taken at 2775 m (oil, gas and water/filtrate) and 2822 m (oil, gas and water/filtrate).
    The well was suspended on 21 September 1990 as an oil discovery.
    Testing
    Two drill stem tests were performed.
    DST 1A tested the interval 2757 - 2776 m in Intra Draupne Formation sandstones. It produced oil and gas at average rates of 379 Sm3/day and 42100 Sm3/day respectively on a 15.9 mm choke. The GOR was 111 Sm3/Sm3, with oil gravity 0.861 g/cc and gas gravity 0.754 (air =1). The flowing well head pressure was 43.6 bars and the bottom hole temperature 107.0 degrees C. The well produced 0.8% CO2 and no H2S.
    DST 1B tested the intervals 2757.0 - 2776.0 m Intra Draupne Formation sandstones and 2779.7 - 2824.7 m in upper Tarbert Formation. Oil flowed at an average rate of 986 Sm3/day and gas flowed at an average rate of 84800 Sm3/day on a 19.1 mm choke. The GOR was 86 Sm3/Sm3, with oil gravity 0.861 g/cc and gas gravity 0.754 (air=l). The flowing well head pressure was 80.8 bars and the bottom hole temperature 108.4 degrees C. The well produced 0.6% CO2 and no H2S.

  • 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]
    1070.00
    3642.00

  • 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
    2725.0
    2725.1
    [m ]
    2
    2726.0
    2729.0
    [m ]
    3
    2730.0
    2732.1
    [m ]
    4
    2747.0
    2771.0
    [m ]
    5
    2774.5
    2824.1
    [m ]
    6
    2825.0
    2871.3
    [m ]
    7
    2872.5
    2895.0
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    147.6
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 2725-2731m
    Core photo at depth: 2731-2750m
    Core photo at depth: 2750-2755m
    Core photo at depth: 2755-2760m
    Core photo at depth: 2760-2765m
    2725-2731m
    2731-2750m
    2750-2755m
    2755-2760m
    2760-2765m
    Core photo at depth: 2765-2770m
    Core photo at depth: 2770-2775m
    Core photo at depth: 2775-2780m
    Core photo at depth: 2780-2785m
    Core photo at depth: 2785-2790m
    2765-2770m
    2770-2775m
    2775-2780m
    2780-2785m
    2785-2790m
    Core photo at depth: 2790-2795m
    Core photo at depth: 2795-2800m
    Core photo at depth: 2800-2805m
    Core photo at depth: 2805-2810m
    Core photo at depth: 2810-2815m
    2790-2795m
    2795-2800m
    2800-2805m
    2805-2810m
    2810-2815m
    Core photo at depth: 2815-2810m
    Core photo at depth: 2820-2824m
    Core photo at depth: 2825-2830m
    Core photo at depth: 2830-2835m
    Core photo at depth: 2835-2840m
    2815-2810m
    2820-2824m
    2825-2830m
    2830-2835m
    2835-2840m
    Core photo at depth: 2840-2845m
    Core photo at depth: 2845-2850m
    Core photo at depth: 2850-2855m
    Core photo at depth: 2855-2860m
    Core photo at depth: 2860-2865m
    2840-2845m
    2845-2850m
    2850-2855m
    2855-2860m
    2860-2865m
    Core photo at depth: 2865-2870m
    Core photo at depth: 2870-2875m
    Core photo at depth: 2875-2880m
    Core photo at depth: 2880-2885m
    Core photo at depth: 2885-2890m
    2865-2870m
    2870-2875m
    2875-2880m
    2880-2885m
    2885-2890m
    Core photo at depth: 2890-2895m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    2890-2895m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1090.0
    [m]
    DC
    RRI
    1130.0
    [m]
    DC
    RRI
    1250.0
    [m]
    DC
    RRI
    1310.0
    [m]
    DC
    RRI
    1330.0
    [m]
    DC
    RRI
    1370.0
    [m]
    DC
    RRI
    1450.0
    [m]
    DC
    RRI
    1470.0
    [m]
    DC
    RRI
    1490.0
    [m]
    DC
    RRI
    1510.0
    [m]
    DC
    RRI
    1530.0
    [m]
    DC
    RRI
    1550.0
    [m]
    DC
    RRI
    1570.0
    [m]
    DC
    RRI
    1590.0
    [m]
    DC
    RRI
    1610.0
    [m]
    DC
    RRI
    1630.0
    [m]
    DC
    RRI
    1650.0
    [m]
    DC
    RRI
    1670.0
    [m]
    DC
    RRI
    1690.0
    [m]
    DC
    RRI
    1710.0
    [m]
    DC
    RRI
    1730.0
    [m]
    DC
    RRI
    1750.0
    [m]
    DC
    RRI
    1770.0
    [m]
    DC
    RRI
    1870.0
    [m]
    DC
    RRI
    1890.0
    [m]
    DC
    RRI
    1910.0
    [m]
    DC
    RRI
    1930.0
    [m]
    DC
    RRI
    1950.0
    [m]
    DC
    RRI
    1970.0
    [m]
    DC
    RRI
    1990.0
    [m]
    DC
    RRI
    2010.0
    [m]
    DC
    RRI
    2030.0
    [m]
    DC
    RRI
    2050.0
    [m]
    DC
    RRI
    2060.0
    [m]
    DC
    RRI
    2070.0
    [m]
    DC
    RRI
    2090.0
    [m]
    DC
    RRI
    2105.0
    [m]
    DC
    RRI
    2120.0
    [m]
    DC
    RRI
    2135.0
    [m]
    DC
    RRI
    2150.0
    [m]
    DC
    RRI
    2165.0
    [m]
    DC
    RRI
    2180.0
    [m]
    DC
    RRI
    2190.0
    [m]
    DC
    RRI
    2210.0
    [m]
    DC
    RRI
    2225.0
    [m]
    DC
    RRI
    2240.0
    [m]
    DC
    RRI
    2255.0
    [m]
    DC
    RRI
    2270.0
    [m]
    DC
    RRI
    2285.0
    [m]
    DC
    RRI
    2300.0
    [m]
    DC
    RRI
    2315.0
    [m]
    DC
    RRI
    2330.0
    [m]
    DC
    RRI
    2345.0
    [m]
    DC
    RRI
    2360.0
    [m]
    DC
    RRI
    2375.0
    [m]
    DC
    RRI
    2410.0
    [m]
    DC
    RRI
    2440.0
    [m]
    DC
    RRI
    2470.0
    [m]
    DC
    RRI
    2500.0
    [m]
    DC
    RRI
    2530.0
    [m]
    DC
    RRI
    2560.0
    [m]
    DC
    RRI
    2590.0
    [m]
    DC
    RRI
    2613.0
    [m]
    SWC
    HYDRO
    2620.0
    [m]
    DC
    RRI
    2650.0
    [m]
    DC
    RRI
    2685.0
    [m]
    DC
    RRI
    2703.0
    [m]
    SWC
    HYDRO
    2706.0
    [m]
    SWC
    HYDRO
    2709.0
    [m]
    SWC
    HYDRO
    2710.0
    [m]
    SWC
    HYDRO
    2712.0
    [m]
    SWC
    HYDRO
    2715.0
    [m]
    DC
    RRI
    2715.0
    [m]
    SWC
    HYDRO
    2719.0
    [m]
    SWC
    HYDRO
    2722.0
    [m]
    SWC
    HYDRO
    2723.0
    [m]
    SWC
    HYDRO
    2725.0
    [m]
    C
    HYDRO
    2726.2
    [m]
    C
    HYDRO
    2727.2
    [m]
    C
    HYDRO
    2728.8
    [m]
    C
    HYDRO
    2730.6
    [m]
    C
    HYDRO
    2731.9
    [m]
    C
    HYDRO
    2737.0
    [m]
    C
    HYDRO
    2740.5
    [m]
    SWC
    HYDRO
    2742.5
    [m]
    SWC
    HYDRO
    2745.0
    [m]
    SWC
    HYDRO
    2747.0
    [m]
    C
    HYDRO
    2748.8
    [m]
    C
    HYDRO
    2749.7
    [m]
    C
    HYDRO
    2750.3
    [m]
    C
    HYDRO
    2750.9
    [m]
    C
    HYDRO
    2755.2
    [m]
    C
    HYDRO
    2759.2
    [m]
    C
    HYDRO
    2763.3
    [m]
    C
    HYDRO
    2767.6
    [m]
    C
    HYDRO
    2769.9
    [m]
    C
    HYDRO
    2771.9
    [m]
    C
    HYDRO
    2773.4
    [m]
    C
    HYDRO
    2775.5
    [m]
    C
    HYDRO
    2777.5
    [m]
    C
    HYDRO
    2779.2
    [m]
    C
    HYDRO
    2781.1
    [m]
    C
    HYDRO
    2781.8
    [m]
    C
    HYDRO
    2782.0
    [m]
    C
    HYDRO
    2782.0
    [m]
    C
    HYDRO
    2792.0
    [m]
    C
    HYDRO
    2792.5
    [m]
    C
    HYDRO
    2796.6
    [m]
    C
    HYDRO
    2797.2
    [m]
    C
    HYDRO
    2803.1
    [m]
    C
    HYDRO
    2804.0
    [m]
    C
    HYDRO
    2812.7
    [m]
    C
    HYDRO
    2813.9
    [m]
    C
    HYDRO
    2815.0
    [m]
    C
    HYDRO
    2819.3
    [m]
    C
    HYDRO
    2825.1
    [m]
    C
    HYDRO
    2827.0
    [m]
    C
    HYDRO
    2830.6
    [m]
    C
    HYDRO
    2836.8
    [m]
    C
    HYDRO
    2839.2
    [m]
    C
    HYDRO
    2844.0
    [m]
    C
    HYDRO
    2845.9
    [m]
    C
    HYDRO
    2848.8
    [m]
    C
    HYDRO
    2851.1
    [m]
    C
    HYDRO
    2857.3
    [m]
    C
    HYDRO
    2864.5
    [m]
    C
    HYDRO
    2867.3
    [m]
    C
    HYDRO
    2868.1
    [m]
    C
    HYDRO
    2869.1
    [m]
    C
    HYDRO
    2872.5
    [m]
    C
    HYDRO
    2876.5
    [m]
    C
    HYDRO
    2883.0
    [m]
    C
    HYDRO
    2886.4
    [m]
    C
    HYDRO
    2891.3
    [m]
    C
    HYDRO
    2892.9
    [m]
    C
    HYDRO
    2899.0
    [m]
    C
    HYDRO
    2908.0
    [m]
    SWC
    HYDRO
    2914.5
    [m]
    SWC
    HYDRO
    2925.0
    [m]
    DC
    RRI
    2932.0
    [m]
    SWC
    HYDRO
    2947.0
    [m]
    SWC
    HYDRO
    2953.0
    [m]
    SWC
    HYDRO
    2965.0
    [m]
    DC
    RRI
    2975.0
    [m]
    DC
    RRI
    2984.0
    [m]
    SWC
    HYDRO
    2992.0
    [m]
    DC
    RRI
    3002.0
    [m]
    DC
    RRI
    3011.0
    [m]
    SWC
    HYDRO
    3022.0
    [m]
    DC
    RRI
    3026.0
    [m]
    SWC
    HYDRO
    3028.0
    [m]
    SWC
    HYDRO
    3036.0
    [m]
    SWC
    HYDRO
    3051.0
    [m]
    SWC
    HYDRO
    3066.0
    [m]
    SWC
    HYDRO
    3082.0
    [m]
    DC
    RRI
    3085.0
    [m]
    SWC
    HYDRO
    3091.5
    [m]
    SWC
    HYDRO
    3095.0
    [m]
    SWC
    HYDRO
    3109.0
    [m]
    SWC
    HYDRO
    3112.0
    [m]
    SWC
    HYDRO
    3115.5
    [m]
    SWC
    HYDRO
    3130.0
    [m]
    DC
    RRI
    3130.0
    [m]
    SWC
    HYDRO
    3131.0
    [m]
    SWC
    HYDRO
    3140.0
    [m]
    DC
    RRI
    3152.0
    [m]
    DC
    RRI
    3162.0
    [m]
    SWC
    HYDRO
    3172.0
    [m]
    DC
    RRI
    3180.0
    [m]
    SWC
    HYDRO
    3192.0
    [m]
    DC
    RRI
    3201.0
    [m]
    SWC
    HYDRO
    3212.0
    [m]
    DC
    RRI
    3232.0
    [m]
    DC
    RRI
    3242.0
    [m]
    DC
    RRI
    3248.0
    [m]
    SWC
    HYDRO
    3262.0
    [m]
    DC
    RRI
    3272.0
    [m]
    DC
    RRI
    3282.0
    [m]
    DC
    RRI
    3295.0
    [m]
    DC
    RRI
    3302.0
    [m]
    DC
    RRI
    3315.0
    [m]
    SWC
    HYDRO
    3322.0
    [m]
    DC
    RRI
    3332.0
    [m]
    DC
    RRI
    3342.0
    [m]
    DC
    RRI
    3352.0
    [m]
    DC
    RRI
    3362.0
    [m]
    DC
    RRI
    3372.0
    [m]
    DC
    RRI
    3382.0
    [m]
    DC
    RRI
    3392.0
    [m]
    DC
    RRI
    3402.0
    [m]
    DC
    RRI
    3412.0
    [m]
    DC
    RRI
    3425.0
    [m]
    SWC
    HYDRO
    3432.0
    [m]
    DC
    RRI
    3446.0
    [m]
    SWC
    HYDRO
    3452.0
    [m]
    DC
    RRI
    3462.0
    [m]
    DC
    RRI
    3478.5
    [m]
    SWC
    HYDRO
    3482.0
    [m]
    DC
    RRI
    3502.0
    [m]
    DC
    RRI
    3512.0
    [m]
    DC
    RRI
    3521.0
    [m]
    SWC
    HYDRO
    3532.0
    [m]
    DC
    RRI
    3542.0
    [m]
    DC
    RRI
    3552.0
    [m]
    DC
    RRI
    3562.0
    [m]
    DC
    RRI
    3572.0
    [m]
    DC
    RRI
    3582.0
    [m]
    DC
    RRI
    3591.0
    [m]
    SWC
    HYDRO
    3602.0
    [m]
    DC
    RRI
    3622.0
    [m]
    DC
    RRI
    3625.0
    [m]
    SWC
    HYDRO
    3637.0
    [m]
    DC
    RRI
    3638.0
    [m]
    SWC
    HYDRO
    3646.0
    [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
    DST1A
    2757.00
    2776.00
    10.12.1990 - 00:00
    YES
    DST
    DST1B
    2779.70
    2824.70
    10.12.1990 - 00:00
    YES

  • Lithostratigraphy

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.55
    pdf
    1.21
    pdf
    4.04

  • 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
    3.43
    pdf
    26.04

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    2757
    2776
    15.9
    2.0
    2757
    2824
    19.1
    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
    379
    421000
    0.861
    0.754
    111
    2.0
    986
    848000
    0.861
    0.754
    86

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL VDL
    2125
    2690
    CST
    2702
    3638
    DIL LSS GR SP AMS
    1041
    2705
    DIL SDT GR SP AMS
    2762
    2868
    DLL MSFL GR AMS
    2701
    2891
    FMS4 GR AMS
    2702
    3651
    LDL CNL
    1041
    2685
    LDL CNL
    2701
    2879
    LDL CNL GR AMS
    2820
    3651
    LWD GR RES DIR
    210
    350
    MWD - GR RES DIR
    124
    3565
    NGL
    2702
    2870
    NGL
    2820
    3642
    RFT AMS
    2757
    3103
    RFT AMS
    2762
    2868
    RFT AMS
    3622
    3634
    VSP
    2200
    3650

  • 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
    209.0
    36
    210.0
    0.00
    LOT
    INTERM.
    13 3/8
    1040.0
    17 1/2
    1059.0
    1.87
    LOT
    INTERM.
    9 5/8
    2701.0
    12 1/4
    2716.0
    1.87
    LOT
    LINER
    7
    2996.0
    8 1/2
    3649.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    124
    1.20
    WATER BASED
    31.07.1990
    210
    1.20
    WATER BASED
    01.08.1990
    224
    1.20
    WATER BASED
    02.08.1990
    350
    1.16
    11.0
    10.0
    WATER BASED
    19.09.1990
    483
    1.20
    WATER BASED
    03.08.1990
    1059
    1.20
    WATER BASED
    06.08.1990
    1059
    1.20
    WATER BASED
    06.08.1990
    1132
    1.20
    10.0
    8.0
    WATER BASED
    06.08.1990
    1984
    1.40
    29.0
    9.0
    WATER BASED
    09.08.1990
    2306
    1.41
    29.0
    9.0
    WATER BASED
    10.08.1990
    2465
    1.40
    26.0
    12.0
    WATER BASED
    13.08.1990
    2716
    1.42
    25.0
    9.0
    WATER BASED
    13.08.1990
    2716
    1.42
    20.0
    11.0
    WATER BASED
    14.08.1990
    2716
    1.42
    25.0
    9.0
    WATER BASED
    13.08.1990
    2725
    1.27
    15.0
    9.0
    WATER BASED
    15.08.1990
    2730
    1.27
    16.0
    8.0
    WATER BASED
    16.08.1990
    2747
    1.28
    17.0
    8.0
    WATER BASED
    17.08.1990
    2774
    1.28
    16.0
    8.0
    WATER BASED
    20.08.1990
    2825
    1.28
    22.0
    8.0
    WATER BASED
    20.08.1990
    2873
    1.27
    19.0
    7.0
    WATER BASED
    20.08.1990
    2895
    1.90
    19.0
    1.0
    WATER BASED
    21.08.1990
    2895
    1.26
    19.0
    7.0
    WATER BASED
    22.08.1990
    3002
    1.22
    13.0
    5.0
    WATER BASED
    31.08.1990
    3002
    1.22
    13.0
    5.0
    WATER BASED
    03.09.1990
    3002
    1.22
    17.0
    10.0
    WATER BASED
    03.09.1990
    3002
    1.22
    18.0
    11.0
    WATER BASED
    04.09.1990
    3002
    1.22
    19.0
    11.0
    WATER BASED
    05.09.1990
    3002
    1.22
    22.0
    10.0
    WATER BASED
    06.09.1990
    3002
    1.22
    22.0
    10.0
    WATER BASED
    07.09.1990
    3002
    1.15
    11.0
    12.0
    WATER BASED
    10.09.1990
    3002
    1.15
    11.0
    13.0
    WATER BASED
    10.09.1990
    3002
    1.15
    11.0
    13.0
    WATER BASED
    10.09.1990
    3002
    1.15
    11.0
    13.0
    WATER BASED
    11.09.1990
    3002
    1.15
    11.0
    13.0
    WATER BASED
    13.09.1990
    3002
    1.15
    11.0
    13.0
    WATER BASED
    14.09.1990
    3002
    1.15
    11.0
    13.0
    WATER BASED
    17.09.1990
    3002
    1.15
    11.0
    10.0
    WATER BASED
    17.09.1990
    3002
    1.16
    11.0
    10.0
    WATER BASED
    18.09.1990
    3002
    1.22
    18.0
    11.0
    WATER BASED
    03.09.1990
    3002
    1.15
    11.0
    13.0
    WATER BASED
    17.09.1990
    3258
    1.27
    18.0
    7.0
    WATER BASED
    23.08.1990
    3649
    1.27
    23.0
    8.0
    WATER BASED
    27.08.1990
    3649
    1.27
    14.0
    6.0
    WATER BASED
    27.08.1990
    3649
    1.27
    21.0
    9.0
    WATER BASED
    27.08.1990
    3649
    1.27
    20.0
    8.0
    WATER BASED
    29.08.1990
    3649
    1.27
    20.0
    7.0
    WATER BASED
    29.08.1990

  • 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