Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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21.04.2024 - 01:32
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6608/10-2

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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.
    6608/10-2
    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.
    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.
    6608/10-2
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    NRGS 85 -NRGS84 - 451& SP. 780
    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.
    701-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.
    94
    Entered date
    The date when he wellbore was spudded. For sidetracks: The date when new formation was drilled by kicking off from the mother-wellbore,
    28.10.1991
    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.
    29.01.1992
    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.
    29.01.1994
    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.
    21.12.2007
    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.
    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.
    FANGST 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.
    BÅT 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.
    374.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3678.0
    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).
    3677.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    4
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    133
    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.
    ÅRE FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    66° 0' 49.35'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    8° 4' 26.48'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7321933.62
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    457994.68
    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.
    1782
  • Wellbore history

    General
    Well 6608/10-2 is located on the Dønna Terrace offshore Mid Norway. The primary objective of the well was to test the hydrocarbon potential in the Middle Jurassic Fangst Group sandstones. Possible sandy equivalent to the Rogn Formation in the Viking Group was a secondary objective. The well was planned with TD at 3225 m with a commitment to drill into rocks of Triassic age.
    Operations and results
    Wildcat well 6608/10-2 was spudded with the semi-submersible installation Ross Rig on 28 October 1991 and drilled to TD at 3678 m in Late Triassic rocks of the Åre Formation. Some problems with tight hole were experienced between 1800 and 2300 m in the 12 1/4" section. Due to presence of hydrocarbons and the commitment to drill to Triassic the well was extended both in time and depth compared to programme. Technical operations went smoothly with little down-time. The well was drilled with seawater and hi-vis pills down to 874 m, with gypsum/PAC mud from 874 m to 2576 m, and with Ancotemp/bentonite mud from 2576 m to TD.
    Shows were observed in limestone in the interval 2160 ? 2271 m in the Cretaceous Nise and Lyr Formations. Oil and gas were encountered in the Båt and Fangst Groups (Lower- Middle Jurassic). From FMT data and electric logs the gas-oil contact was interpreted at 2605 m, and the oil-water contact at 2713.5 m. The Rogn Formation equivalent was not present in the well.
    A total of 141.5 m core was recovered in six cores from the interval 2590 ? 2741 m in the Fangst and Båt Groups. Two FMT wire line samples were collected; a gas sample at 2583.2 m and an oil sample at 2650.5 m.
    The well was permanently abandoned on 29 January 1992 as an oil and gas discovery.
    Testing
    Four intervals were perforated and tested.
    DST 1 tested the interval 2715 ? 2720 m in the in the lower Tofte Formation. The test produced 310 Sm3 water /day through a 2" choke. Maximum bottom hole temperature recorded in the test was 100 deg C.
    DST 2 tested the interval 2673 ? 2695 m in the in the upper Tofte Formation. The test produced up to 1165 Sm3 oil and 108667 Sm3 gas /day through a 1.5" choke. The GOR in this flow was 93 Sm3/Sm3, the oil density was 0.856 g/cm3, the gas gravity was 0.65 (air =1), and the gas contained 1.8 % CO2 and 4 ppm H2S. Maximum bottom hole temperature recorded in the test was 98.4 deg C.
    DST 3A tested the interval 2605 ? 2610 m in the in the lower Garn Formation. The production rate was measured to 33 Sm3 condensate and 582600 Sm3 gas/day through a 19.05 mm choke. The GOR was 17654 Sm3/Sm3. Maximum bottom hole temperature recorded in the test was 91.4 deg C.
    DST 3B tested the interval 2590 - 2603 m in the in the Garn Formation. Maximum rates were recorded to 100 Sm3 condensate and 945000 Sm3 gas /day through a 38.1 mm choke. The GOR was 9450 Sm3/Sm3 in this flow, the condensate density was 0.783 g/cm3, the gas gravity was 0.645 (air = 1), and the gas contained 1.1 % CO2 and 0.5 ppm H2S. Maximum bottom hole temperature recorded in the test was 95.5 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]
    890.00
    3678.00
  • 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
    2590.0
    2616.7
    [m ]
    2
    2617.6
    2641.0
    [m ]
    3
    2646.0
    2673.8
    [m ]
    4
    2674.0
    2681.8
    [m ]
    5
    2686.0
    2714.2
    [m ]
    6
    2714.2
    2741.8
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    141.5
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES
  • Core photos

    Core photos
    Core photo at depth: 2590-2595m
    Core photo at depth: 2595-2600m
    Core photo at depth: 2600-2605m
    Core photo at depth: 2605-2610m
    Core photo at depth: 2610-2615m
    2590-2595m
    2595-2600m
    2600-2605m
    2605-2610m
    2610-2615m
    Core photo at depth: 2615-2616m
    Core photo at depth: 2617-2622m
    Core photo at depth: 2622-2627m
    Core photo at depth: 2627-2632m
    Core photo at depth: 2632-2637m
    2615-2616m
    2617-2622m
    2622-2627m
    2627-2632m
    2632-2637m
    Core photo at depth: 2637-2542m
    Core photo at depth: 2642-2646m
    Core photo at depth: 2646-2651m
    Core photo at depth: 2651-2656m
    Core photo at depth: 2656-2661m
    2637-2542m
    2642-2646m
    2646-2651m
    2651-2656m
    2656-2661m
    Core photo at depth: 2661-2666m
    Core photo at depth: 2666-2671m
    Core photo at depth: 2671-2673m
    Core photo at depth: 2674-2679m
    Core photo at depth: 2679-2681m
    2661-2666m
    2666-2671m
    2671-2673m
    2674-2679m
    2679-2681m
    Core photo at depth: 2686-2691m
    Core photo at depth: 2691-2696m
    Core photo at depth: 2696-2701m
    Core photo at depth: 2701-2706m
    Core photo at depth: 2706-2711m
    2686-2691m
    2691-2696m
    2696-2701m
    2701-2706m
    2706-2711m
    Core photo at depth: 2711-2714m
    Core photo at depth: 2714-2719m
    Core photo at depth: 2719-2724m
    Core photo at depth: 2724-2729m
    Core photo at depth: 2729-2734m
    2711-2714m
    2714-2719m
    2719-2724m
    2724-2729m
    2729-2734m
    Core photo at depth: 2734-2739m
    Core photo at depth: 2739-2741m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    2734-2739m
    2739-2741m
  • Palynological slides at the Norwegian Offshore Directorate

    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1420.0
    [m]
    SWC
    STATO
    1553.0
    [m]
    SWC
    STATO
    1572.0
    [m]
    DC
    RRI
    1614.0
    [m]
    DC
    RRI
    1632.0
    [m]
    DC
    RRI
    1650.0
    [m]
    DC
    RRI
    1678.0
    [m]
    SWC
    STATO
    1680.0
    [m]
    DC
    RRI
    1684.0
    [m]
    SWC
    STATO
    1704.0
    [m]
    DC
    RRI
    1722.0
    [m]
    DC
    RRI
    1740.0
    [m]
    DC
    RRI
    1776.0
    [m]
    DC
    RRI
    1806.0
    [m]
    DC
    RRI
    1824.0
    [m]
    DC
    RRI
    1846.0
    [m]
    DC
    RRI
    1854.0
    [m]
    DC
    RRI
    1857.0
    [m]
    SWC
    STATO
    1860.0
    [m]
    SWC
    STATO
    1887.0
    [m]
    SWC
    STATO
    1898.0
    [m]
    SWC
    STATO
    1932.0
    [m]
    DC
    RRI
    1947.0
    [m]
    SWC
    STATO
    1953.0
    [m]
    SWC
    STATO
    1965.0
    [m]
    SWC
    STATO
    1985.0
    [m]
    SWC
    STATO
    1986.0
    [m]
    DC
    RRI
    2051.0
    [m]
    SWC
    STATO
    2085.0
    [m]
    SWC
    STATO
    2137.0
    [m]
    SWC
    STATO
    2200.0
    [m]
    SWC
    STATO
    2249.0
    [m]
    SWC
    STATO
    2256.0
    [m]
    SWC
    STATO
    2331.0
    [m]
    SWC
    STATO
    2348.0
    [m]
    SWC
    STATO
    2352.0
    [m]
    DC
    STATO
    2355.0
    [m]
    DC
    STATO
    2358.0
    [m]
    DC
    STATO
    2360.0
    [m]
    SWC
    STATO
    2368.0
    [m]
    SWC
    STATO
    2375.0
    [m]
    SWC
    STATO
    2385.0
    [m]
    SWC
    STATO
    2444.0
    [m]
    SWC
    STATO
    2481.0
    [m]
    DC
    RRI
    2490.0
    [m]
    DC
    RRI
    2502.0
    [m]
    DC
    RRI
    2511.0
    [m]
    DC
    RRI
    2523.0
    [m]
    DC
    RRI
    2532.0
    [m]
    DC
    RRI
    2550.0
    [m]
    DC
    RRI
    2559.0
    [m]
    DC
    RRI
    2576.0
    [m]
    DC
    RRI
    2615.6
    [m]
    C
    STATOIL
    2617.4
    [m]
    C
    STATOIL
    2618.8
    [m]
    C
    STATO
    2620.7
    [m]
    C
    STATOI
    2621.1
    [m]
    C
    STATOI
    2627.4
    [m]
    C
    STATOI
    2629.9
    [m]
    C
    STATOI
    2630.6
    [m]
    C
    STATOI
    2633.3
    [m]
    C
    STATOI
    2636.4
    [m]
    C
    STATOI
    2637.3
    [m]
    C
    STATOI
    2638.2
    [m]
    C
    STATOI
    2640.4
    [m]
    C
    STATOI
    2641.9
    [m]
    C
    STATOI
    2645.1
    [m]
    C
    STATOI
    2649.5
    [m]
    C
    STATOI
    2650.7
    [m]
    C
    STATOI
    2652.0
    [m]
    C
    STATOI
    2652.6
    [m]
    C
    STATO
    2653.4
    [m]
    C
    STATOI
    2654.2
    [m]
    C
    STATOI
    2657.6
    [m]
    C
    STATOI
    2659.8
    [m]
    C
    STATO
    2662.5
    [m]
    C
    STATO
    2678.3
    [m]
    C
    STATO
    2692.5
    [m]
    C
    STATO
    2701.5
    [m]
    C
    STATO
    2710.8
    [m]
    C
    STATO
    2721.5
    [m]
    C
    STATO
    2721.9
    [m]
    C
    STATO
    2724.5
    [m]
    C
    STATO
    2724.7
    [m]
    C
    STATO
    2726.0
    [m]
    C
    STATO
    2738.3
    [m]
    C
    STATO
    2761.0
    [m]
    SWC
    STATO
    2773.0
    [m]
    DC
    RRI
    2787.0
    [m]
    SWC
    STATO
    2794.0
    [m]
    DC
    RRI
    2818.0
    [m]
    DC
    RRI
    2822.0
    [m]
    SWC
    STATO
    2836.0
    [m]
    DC
    RRI
    2842.0
    [m]
    DC
    RRI
    2866.0
    [m]
    DC
    RRI
    2875.0
    [m]
    SWC
    STATO
    2884.0
    [m]
    DC
    RRI
    2896.0
    [m]
    DC
    RRI
    2908.0
    [m]
    DC
    RRI
    2918.5
    [m]
    SWC
    STATO
    2926.0
    [m]
    DC
    RRI
    2938.0
    [m]
    DC
    RRI
    2944.0
    [m]
    DC
    RRI
    2956.0
    [m]
    DC
    RRI
    2962.0
    [m]
    DC
    RRI
    2974.0
    [m]
    DC
    RRI
    2978.0
    [m]
    SWC
    STATO
    2992.0
    [m]
    DC
    RRI
    3004.0
    [m]
    DC
    RRI
    3016.0
    [m]
    DC
    RRI
    3025.0
    [m]
    SWC
    STATO
    3034.0
    [m]
    DC
    RRI
    3043.0
    [m]
    DC
    RRI
    3053.0
    [m]
    SWC
    STATO
    3063.0
    [m]
    DC
    RRI
    3072.0
    [m]
    DC
    RRI
    3080.0
    [m]
    SWC
    STATO
    3087.0
    [m]
    DC
    RRI
    3100.0
    [m]
    SWC
    STATO
    3117.0
    [m]
    DC
    RRI
    3125.0
    [m]
    SWC
    STATO
    3135.0
    [m]
    DC
    RRI
    3144.0
    [m]
    DC
    RRI
    3153.0
    [m]
    DC
    RRI
    3162.0
    [m]
    DC
    RRI
    3171.0
    [m]
    DC
    RRI
    3180.0
    [m]
    DC
    RRI
    3189.0
    [m]
    DC
    RRI
    3198.0
    [m]
    DC
    RRI
    3210.0
    [m]
    SWC
    STATO
    3219.0
    [m]
    DC
    RRI
    3229.5
    [m]
    SWC
    STATO
    3240.0
    [m]
    DC
    RRI
    3249.0
    [m]
    DC
    RRI
    3262.0
    [m]
    SWC
    STATO
    3280.0
    [m]
    SWC
    STATO
    3290.0
    [m]
    SWC
    STATO
    3309.0
    [m]
    DC
    RRI
    3318.0
    [m]
    DC
    RRI
    3325.0
    [m]
    SWC
    STATO
    3335.0
    [m]
    DC
    RRI
    3343.0
    [m]
    SWC
    STATO
    3354.0
    [m]
    DC
    RRI
    3363.0
    [m]
    DC
    RRI
    3370.0
    [m]
    SWC
    STATO
    3381.0
    [m]
    DC
    RRI
    3417.0
    [m]
    DC
    RRI
    3426.0
    [m]
    SWC
    STATO
    3435.0
    [m]
    DC
    RRI
    3453.0
    [m]
    DC
    RRI
    3481.5
    [m]
    SWC
    STATO
    3518.0
    [m]
    SWC
    STATO
    3528.0
    [m]
    DC
    RRI
    3537.0
    [m]
    DC
    RRI
    3558.0
    [m]
    DC
    RRI
    3570.5
    [m]
    SWC
    STATO
    3582.0
    [m]
    DC
    RRI
    3594.0
    [m]
    DC
    RRI
    3600.0
    [m]
    DC
    RRI
    3618.0
    [m]
    DC
    RRI
    3618.0
    [m]
    DC
    OD
    3627.0
    [m]
    SWC
    STATO
    3636.0
    [m]
    DC
    RRI
    3648.0
    [m]
    DC
    RRI
    3652.0
    [m]
    DC
    OD
    3653.0
    [m]
    SWC
    STATO
    3654.5
    [m]
    SWC
    STATO
    3660.9
    [m]
    SWC
    STATO
    3661.0
    [m]
    DC
    OD
    3669.0
    [m]
    DC
    RRI
    3670.0
    [m]
    DC
    OD
    3678.0
    [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
    DST2
    2673.00
    2695.00
    04.01.1992 - 16:30
    YES
    DST
    DST3A
    2603.00
    2606.00
    10.01.1992 - 09:30
    YES
    DST
    DST3B
    2603.00
    2606.00
    13.01.1992 - 20:00
    YES
  • Lithostratigraphy

  • Geochemical information

    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.27
    pdf
    0.65
    pdf
    0.10
    pdf
    2.96
  • 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
    42.32
  • Drill stem tests (DST)

    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    2715
    2720
    50.8
    3.1
    2673
    2696
    72.0
    3.2
    2605
    2610
    19.0
    3.3
    2590
    2610
    28.0
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    100
    3.1
    30.000
    98
    3.2
    91
    3.3
    95
    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
    0.680
    3.1
    1165
    0.847
    0.660
    93
    3.2
    582600
    0.640
    3.3
    945000
    0.640
  • Logs

    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    ACBL GR
    1563
    2559
    ACBL GR
    2405
    3319
    CBL VDL GR
    394
    1520
    DIFL ACL GR
    867
    3661
    DIPLOG GR
    1520
    2140
    DIPLOG GR
    2559
    3332
    DIPLOG GR
    3329
    3661
    DLL MLL SL
    2559
    2758
    FMT HP GR
    2579
    2800
    FMT HP GR
    2650
    2650
    LWD - CDR CDN
    2100
    2573
    MWD
    465
    3335
    VELOCITY
    930
    3640
    ZDL CNL CAL GR
    1520
    2141
    ZDL CNL CAL GR
    2559
    3644
    ZDL GR
    867
    1525
  • 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
    459.0
    36
    460.0
    0.00
    LOT
    INTERM.
    20
    867.0
    26
    870.0
    1.41
    LOT
    INTERM.
    13 3/8
    1520.0
    17 1/2
    1522.0
    1.86
    LOT
    INTERM.
    9 5/8
    2561.0
    12 1/4
    2564.0
    1.95
    LOT
    LINER
    7
    3330.0
    8 1/2
    3678.0
    1.82
    LOT
  • Drilling mud

    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    886
    1.03
    23.0
    WATER BASED
    920
    1.20
    20.0
    WATER BASED
    1220
    1.20
    20.0
    WATER BASED
    1540
    1.37
    29.0
    WATER BASED
    1542
    1.37
    23.0
    WATER BASED
    1727
    1.50
    24.0
    WATER BASED
    1828
    1.64
    28.0
    WATER BASED
    1911
    1.62
    36.0
    WATER BASED
    2041
    1.62
    33.0
    WATER BASED
    2561
    1.20
    15.0
    WATER BASED
    2576
    1.30
    22.0
    WATER BASED
    2579
    1.20
    14.0
    WATER BASED
    2590
    1.30
    23.0
    WATER BASED
    2674
    1.30
    20.0
    WATER BASED
    2682
    1.30
    20.0
    WATER BASED
    2741
    1.30
    22.0
    WATER BASED
    3013
    1.30
    21.0
    WATER BASED
    3051
    1.30
    20.0
    WATER BASED
    3073
    1.25
    21.0
    WATER BASED
    3276
    1.20
    15.0
    WATER BASED
    3282
    1.20
    16.0
    WATER BASED
    3330
    1.20
    15.0
    WATER BASED
    3335
    1.20
    15.0
    WATER BASED
    3445
    1.20
    18.0
    WATER BASED
    3617
    1.20
    15.0
    WATER BASED
    3678
    1.20
    17.0
    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
    0.30