Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
28.04.2024 - 01:35
Time of last synchronization with Norwegian Offshore Directorate's internal systems

6507/11-3

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.
    6507/11-3
    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.
    NORWEGIAN 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.
    6507/11-3
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    SG 8458 - 412 SP. 526
    Production licence
    Official designation of the production licence the wellbore was drilled or planned to be drilled from ( well head posistion).
    Drilling operator
    Name of the licensee starting the drilling operation on behalf of the active production license (well head position). This will usually equal the operator of the production license.
    Saga Petroleum ASA
    Drill permit
    The drilling permit number together with the version of the drilling permit as stated in the drilling permit granted by the Norwegian Offshore Directorate.
    469-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.
    71
    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,
    03.06.1985
    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.
    15.08.1985
    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.
    15.08.1987
    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.
    13.12.2005
    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.
    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.
    GARN FM
    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.
    ILE FM
    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.
    290.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3250.0
    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).
    3250.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    2.8
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    107
    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.
    GREY BEDS (INFORMAL)
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    65° 1' 59.8'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    7° 30' 42.34'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7213169.06
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    429908.44
    UTM zone
    Universal Transverse Mercator zone. Examples of legal values: 31, 32, 33, 34.
    32
    NPDID wellbore
    Norwegian Offshore Directorate's unique id for the wellbore.
    470

  • Wellbore history
    General
    Well 6507/11-3 was designed to test the Beta Fault compartment of the Midgard Discovery off shore Mid Norway. The Beta segment is a part of the Midgard horst. This horst is defined by NNV trending normal faults. It is separated from the other compartments by a ENE trending cross fault and exhibits true vertical closure at Base Cretaceous level. The primary target was reservoir rocks of the Middle Jurassic Fangst Group with the objective to establish the GWC within a good sand and to perform a DST in a formation not previously being tested (the Ile Formation). The location was chosen relatively high on the structure in case the hydrocarbon contact for Beta was different from what was seen in the Alpha and Gamma structures. The well should reach Triassic rocks or drill to 500 m below the coal reflector. The proposed depth was 3250 m. The pre-drill classification of the well was wildcat.
    The well is Type Well for the Ile and Not Formation of the Fangst Group.
    Operations and results
    Well 6507/11-3 was spudded with the semi-submersible installation Treasure Saga on 3 June 1985 and drilled to TD at 3250 m in the Triassic Grey Beds. While drilling the reservoir, mud weight had to be raised gradually to 1.6 g/cm3 due to high trip gas. Approximately 2 weeks were lost due to a work conflict. The well was drilled with spud mud down to 421 m, with gel mud from 421 m to 868 m, with gypsum/polymer mud from 868 m to 2615 m, and with gel mud from 2615 m to TD.
    The average background gas down to the 20" casing point was 0.4% to 0.8% with peaks at 505 m (3.43%), 540 m (1.08%), 576 m (1.76%) and 663 m (1.97%). Methane was the only gas component present. The well proved mainly claystones down to the Fangst Group. The Cainozoic with a total thickness of 1771 m overlies a 271 m Cretaceous sequence. Late Jurassic consisted of 14.5 m hot shale of the Spekk Formation and 39.5 m of silty claystones of the Melke Formation. The Fangst Group consisted of the Garn, Not, and Ile Formations as in the other wells in the area. The Garn and the Ile Formations had very good reservoir properties, while the Not Formation is a non-reservoir zone in between. Two mudstone SWC's at 2170 m and 2197 m in the Shetland Group had oil shows. The first oil shows below this depth were observed in the Melke Formation at 2393 m. The Fangst Group had gas above a thin oil zone. The GOC was encountered at 2514 m, and the OWC at 2525.5 m. There were no shows below OWC.
    Six cores were cut in the Fangst Group and another three cores were cut in the Tilje Formation. Six segregated fluid samples were taken on FMT; four at 2426.5 m, 2456 m, 2473.5 m, and 2512 m in the gas/condensate zone, and at two at 2516.3 m and at 2520 m in the oil zone.
    The well was permanently abandoned on 15 August 1985 as an oil/gas discovery
    Testing
    Three drill stem tests were performed; one in the oil zone and two in the gas zone.
    DST 1 tested the oil zone from 2519.0 m to 2520.5 m. Rates were increased in steps up to 1500 Sm3/day to investigate gas coning behaviour. The GOR without gas coning was ca 140 Sm3/Sm3. Stock tank oil gravity was 0.8506 g/cm3.
    DST 2 tested the interval 2495.7 m to 2508.7 in the gas zone and flowed 564000 Sm3 gas/day through a 14.3 mm choke in the main flow. The gas/condensate ratio of the fluid was 6850 Sm3/Sm3.
    DST 3 tested the interval from 2413.0 m to 2419.5 m in the gas zone and flowed 584000 Sm3 gas/day through a 14.3 mm choke in the main flow. The gas/condensate ratio of the fluid was 7100 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]
    430.00
    3250.00

  • 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
    2428.0
    2437.5
    [m ]
    2
    2437.5
    2456.0
    [m ]
    3
    2456.0
    2465.3
    [m ]
    4
    2467.0
    2494.5
    [m ]
    5
    2494.5
    2522.0
    [m ]
    6
    2522.0
    2536.8
    [m ]
    7
    2636.0
    2643.9
    [m ]
    8
    2650.0
    2660.2
    [m ]
    9
    2668.5
    2677.5
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    134.2
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 2428-2433m
    Core photo at depth: 2433-2437m
    Core photo at depth: 2437-2443m
    Core photo at depth: 2442-2447m
    Core photo at depth: 2447-2452m
    2428-2433m
    2433-2437m
    2437-2443m
    2442-2447m
    2447-2452m
    Core photo at depth: 2452-2456m
    Core photo at depth: 2456-2461m
    Core photo at depth: 2461-2465m
    Core photo at depth: 2467-2472m
    Core photo at depth: 2472-2477m
    2452-2456m
    2456-2461m
    2461-2465m
    2467-2472m
    2472-2477m
    Core photo at depth: 2477-2482m
    Core photo at depth: 2482-2487m
    Core photo at depth: 2487-2492m
    Core photo at depth: 2492-2494m
    Core photo at depth: 2494-2499m
    2477-2482m
    2482-2487m
    2487-2492m
    2492-2494m
    2494-2499m
    Core photo at depth: 2499-2504m
    Core photo at depth: 2504-2509m
    Core photo at depth: 2509-2514m
    Core photo at depth: 2514-2519m
    Core photo at depth: 2519-2522m
    2499-2504m
    2504-2509m
    2509-2514m
    2514-2519m
    2519-2522m
    Core photo at depth: 2522-2527m
    Core photo at depth: 2527-2532m
    Core photo at depth: 2532-2536m
    Core photo at depth: 2634-2640m
    Core photo at depth: 2640-2643m
    2522-2527m
    2527-2532m
    2532-2536m
    2634-2640m
    2640-2643m
    Core photo at depth: 2650-2656m
    Core photo at depth: 2656-2660m
    Core photo at depth: 2668-2674m
    Core photo at depth: 2674-2677m
    Core photo at depth:  
    2650-2656m
    2656-2660m
    2668-2674m
    2674-2677m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1910.0
    [m]
    DC
    STRAT
    1920.0
    [m]
    SWC
    STRAT
    1930.0
    [m]
    DC
    STRAT
    1950.0
    [m]
    DC
    STRAT
    1965.0
    [m]
    SWC
    STRAT
    1974.0
    [m]
    SWC
    STRAT
    1980.0
    [m]
    DC
    STRAT
    2003.0
    [m]
    SWC
    STRAT
    2010.0
    [m]
    DC
    STRAT
    2022.0
    [m]
    SWC
    STRAT
    2026.0
    [m]
    SWC
    STRAT
    2050.0
    [m]
    DC
    STRAT
    2060.0
    [m]
    SWC
    STRAT
    2070.0
    [m]
    DC
    STRAT
    2083.0
    [m]
    SWC
    STRAT
    2086.0
    [m]
    SWC
    STRAT
    2091.0
    [m]
    SWC
    STRAT
    2109.0
    [m]
    SWC
    STRAT
    2120.0
    [m]
    DC
    STRAT
    2130.0
    [m]
    SWC
    STRAT
    2143.0
    [m]
    SWC
    STRAT
    2150.0
    [m]
    DC
    STRAT
    2160.0
    [m]
    DC
    STRAT
    2170.0
    [m]
    SWC
    STRAT
    2180.0
    [m]
    DC
    STRAT
    2190.0
    [m]
    DC
    STRAT
    2197.0
    [m]
    SWC
    STRAT
    2210.0
    [m]
    DC
    STRAT
    2220.0
    [m]
    DC
    STRAT
    2227.0
    [m]
    SWC
    STRAT
    2240.0
    [m]
    DC
    STRAT
    2251.0
    [m]
    SWC
    STRAT
    2260.0
    [m]
    DC
    STRAT
    2267.0
    [m]
    SWC
    STRAT
    2280.0
    [m]
    DC
    STRAT
    2285.0
    [m]
    SWC
    STRAT
    2289.0
    [m]
    SWC
    STRAT
    2295.0
    [m]
    DC
    STRAT
    2295.0
    [m]
    SWC
    STRAT
    2310.0
    [m]
    DC
    STRAT
    2320.0
    [m]
    DC
    STRAT
    2331.0
    [m]
    SWC
    STRAT
    2340.0
    [m]
    DC
    STRAT
    2359.0
    [m]
    SWC
    STRAT
    2366.5
    [m]
    SWC
    STRAT
    2372.0
    [m]
    SWC
    STRAT
    2383.0
    [m]
    SWC
    STRAT
    2393.5
    [m]
    SWC
    STRAT
    2404.0
    [m]
    SWC
    STRAT
    2413.0
    [m]
    SWC
    STRAT
    2420.0
    [m]
    SWC
    STRAT
    2439.6
    [m]
    C
    STRAT
    2457.0
    [m]
    C
    STRAT
    2465.0
    [m]
    C
    STRAT
    2467.0
    [m]
    C
    STRAT
    2475.0
    [m]
    C
    STRAT
    2481.7
    [m]
    C
    STRAT
    2491.1
    [m]
    C
    STRAT
    2499.0
    [m]
    C
    STRAT
    2508.4
    [m]
    C
    STRAT
    2517.5
    [m]
    C
    STRAT
    2530.0
    [m]
    C
    STRAT
    2536.7
    [m]
    C
    STRAT
    2539.0
    [m]
    DC
    STRAT
    2546.0
    [m]
    SWC
    STRAT
    2551.0
    [m]
    DC
    STRAT
    2559.5
    [m]
    SWC
    STRAT
    2569.0
    [m]
    DC
    STRAT
    2579.0
    [m]
    SWC
    STRAT
    2588.0
    [m]
    SWC
    STRAT
    2600.0
    [m]
    SWC
    STRAT
    2611.0
    [m]
    DC
    STRAT
    2620.0
    [m]
    DC
    STRAT
    2631.5
    [m]
    SWC
    STRAT
    2634.0
    [m]
    C
    STRAT
    2642.8
    [m]
    C
    STRAT
    2645.0
    [m]
    SWC
    STRAT
    2653.9
    [m]
    C
    STRAT
    2669.0
    [m]
    C
    STRAT
    2676.7
    [m]
    C
    STRAT
    2677.5
    [m]
    SWC
    STRAT
    2682.5
    [m]
    SWC
    STRAT
    2686.0
    [m]
    DC
    STRAT
    2695.0
    [m]
    DC
    STRAT
    2701.0
    [m]
    DC
    STRAT
    2707.0
    [m]
    DC
    STRAT
    2718.0
    [m]
    SWC
    STRAT
    2727.5
    [m]
    SWC
    STRAT
    2734.0
    [m]
    DC
    STRAT
    2747.0
    [m]
    SWC
    STRAT
    2749.0
    [m]
    DC
    STRAT
    2758.0
    [m]
    DC
    STRAT
    2761.0
    [m]
    SWC
    STRAT
    2773.0
    [m]
    DC
    STRAT
    2779.0
    [m]
    DC
    STRAT
    2785.0
    [m]
    DC
    STRAT
    2790.7
    [m]
    SWC
    STRAT
    2800.0
    [m]
    DC
    STRAT
    2803.0
    [m]
    SWC
    STRAT
    2815.0
    [m]
    DC
    STRAT
    2818.3
    [m]
    SWC
    STRAT
    2821.0
    [m]
    DC
    STRAT
    2825.5
    [m]
    SWC
    STRAT
    2830.0
    [m]
    SWC
    STRAT
    2842.0
    [m]
    DC
    STRAT
    2848.0
    [m]
    DC
    STRAT
    2854.0
    [m]
    DC
    STRAT
    2863.0
    [m]
    DC
    STRAT
    2869.0
    [m]
    DC
    STRAT
    2878.0
    [m]
    DC
    STRAT
    2884.0
    [m]
    DC
    STRAT
    2887.0
    [m]
    SWC
    STRAT
    2899.0
    [m]
    DC
    STRAT
    2906.5
    [m]
    SWC
    STRAT
    2913.0
    [m]
    SWC
    STRAT
    2916.0
    [m]
    SWC
    STRAT
    2919.6
    [m]
    SWC
    STRAT
    2924.5
    [m]
    SWC
    STRAT
    2929.7
    [m]
    SWC
    STRAT
    2938.0
    [m]
    DC
    STRAT
    2943.9
    [m]
    SWC
    STRAT
    2953.0
    [m]
    DC
    STRAT
    2957.6
    [m]
    SWC
    STRAT
    2968.0
    [m]
    DC
    STRAT
    2973.2
    [m]
    SWC
    STRAT
    2980.0
    [m]
    DC
    STRAT
    2989.0
    [m]
    DC
    STRAT
    2998.4
    [m]
    SWC
    STRAT
    3001.0
    [m]
    DC
    STRAT
    3010.0
    [m]
    DC
    STRAT
    3016.0
    [m]
    DC
    STRAT
    3022.0
    [m]
    DC
    STRAT
    3031.0
    [m]
    DC
    STRAT
    3034.0
    [m]
    SWC
    STRAT
    3041.7
    [m]
    SWC
    STRAT
    3052.0
    [m]
    DC
    STRAT
    3058.0
    [m]
    DC
    STRAT
    3064.0
    [m]
    DC
    STRAT
    3072.0
    [m]
    SWC
    STRAT
    3079.0
    [m]
    DC
    STRAT
    3085.0
    [m]
    DC
    STRAT
    3091.0
    [m]
    SWC
    STRAT
    3100.0
    [m]
    DC
    STRAT
    3106.0
    [m]
    DC
    STRAT
    3114.5
    [m]
    SWC
    STRAT
    3121.0
    [m]
    DC
    STRAT
    3127.0
    [m]
    DC
    STRAT
    3136.0
    [m]
    DC
    STRAT
    3139.0
    [m]
    SWC
    STRAT
    3142.0
    [m]
    SWC
    STRAT
    3148.0
    [m]
    DC
    STRAT
    3157.0
    [m]
    DC
    STRAT
    3165.2
    [m]
    SWC
    STRAT
    3169.0
    [m]
    DC
    STRAT
    3178.0
    [m]
    DC
    STRAT
    3182.0
    [m]
    SWC
    STRAT
    3189.5
    [m]
    SWC
    STRAT
    3196.5
    [m]
    SWC
    STRAT
    3203.5
    [m]
    SWC
    STRAT
    3213.0
    [m]
    SWC
    STRAT
    3220.0
    [m]
    DC
    STRAT
    3223.0
    [m]
    SWC
    STRAT
    3232.0
    [m]
    DC
    STRAT
    3241.0
    [m]
    DC
    STRAT
    3247.0
    [m]
    DC
    STRAT
    3250.0
    [m]
    DC
    STRAT

  • 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
    2519.00
    2521.00
    01.08.1985 - 16:30
    YES
    DST
    DST2
    2495.00
    2508.00
    05.08.1985 - 17:00
    YES
    DST
    DST3
    2412.50
    2419.50
    10.08.1985 - 10:53
    YES

  • Lithostratigraphy

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    3.57

  • 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
    14.82

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    2519
    2521
    25.4
    2.0
    2496
    2509
    31.8
    3.0
    2413
    2420
    38.1
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    23.000
    8.000
    23.000
    90
    2.0
    24.000
    12.000
    20.000
    90
    3.0
    25.000
    10.000
    24.000
    90
    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
    1490
    29500
    0.847
    0.720
    198
    2.0
    1480000
    0.690
    3.0
    1740000
    0.670

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL VDL
    730
    1902
    CBL VDL
    1700
    2599
    CDL CNL GR
    1902
    2615
    CDL CNL GR
    2659
    3242
    COREGUN
    2428
    2677
    CORGUN
    2635
    2679
    DIFL LS BHC CDL CBL GR
    849
    1918
    DIFL LS BHC GR
    1902
    2615
    DIFL LS BHC GR
    2659
    3243
    DIPLOG
    1902
    2609
    DIPLOG
    2659
    3243
    DLL MLL GR
    2320
    2610
    FMT
    2414
    2536
    FMT
    2442
    3226
    MWD - GR RES DIR
    415
    3246
    VSP
    1750
    3250

  • 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
    414.0
    36
    449.0
    0.00
    LOT
    SURF.COND.
    20
    849.0
    26
    868.0
    1.52
    LOT
    INTERM.
    13 3/8
    1903.0
    17 1/2
    1918.0
    1.83
    LOT
    INTERM.
    9 5/8
    2600.0
    12 1/4
    2615.0
    1.79
    LOT
    OPEN HOLE
    3250.0
    8 1/2
    3250.0
    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
    1.05
    47.0
    25.0
    WATER BASED
    07.06.1985
    763
    1.17
    50.0
    29.0
    WATER BASED
    10.06.1985
    868
    1.18
    43.0
    33.0
    WATER BASED
    10.06.1985
    873
    1.15
    14.0
    25.0
    WATER BASED
    02.07.1985
    1300
    1.20
    16.0
    20.0
    WATER BASED
    02.07.1985
    1580
    1.23
    18.0
    22.0
    WATER BASED
    02.07.1985
    1918
    1.40
    67.0
    19.0
    WATER BASED
    03.07.1985
    1918
    1.40
    60.0
    18.0
    WATER BASED
    04.07.1985
    1918
    1.40
    12.0
    18.0
    WATER BASED
    08.07.1985
    1918
    1.40
    67.0
    19.0
    WATER BASED
    03.07.1985
    1918
    1.40
    60.0
    18.0
    WATER BASED
    04.07.1985
    1918
    1.40
    12.0
    18.0
    WATER BASED
    08.07.1985
    1918
    1.40
    65.0
    25.0
    WATER BASED
    02.07.1985
    2151
    1.53
    25.0
    19.0
    WATER BASED
    08.07.1985
    2318
    1.53
    37.0
    23.0
    WATER BASED
    08.07.1985
    2402
    1.60
    36.0
    17.0
    WATER BASED
    11.07.1985
    2545
    1.30
    58.0
    10.0
    WATER BASED
    29.07.1985
    2623
    1.26
    17.0
    10.0
    WATER BASED
    22.07.1985
    2644
    1.21
    17.0
    10.0
    WATER BASED
    22.07.1985
    2680
    1.20
    17.0
    10.0
    WATER BASED
    22.07.1985

  • 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
    0.27