Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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24.11.2024 - 01:27
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33/9-9

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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.
    33/9-9
    Type
    Wellbore type. Legal values: EXPLORATION, DEVELOPMENT, OTHER (see 'Purpose' for more information)
    EXPLORATION
    Purpose
    Final classification of the wellbore.

    Legal values for exploration wellbores:
    WILDCAT, APPRAISAL, WILDCAT-CCS, APPRAISAL-CCS.

    Legal values for development wellbores:
    OBSERVATION, PRODUCTION, INJECTION, INJECTION-CCS, OBSERVATION-CCS.

    Legal values for other wellbores:
    SOIL DRILLING (drilling in connection with track surveys and other subsurface surveys to investigate the soil conditions prior to placement of facilities),
    SHALLOW GAS (drilling to investigate shallow gas before the first 'real' drilling on the location),
    PILOT (drilling to investigate the geology and fluid connectors for location of the main wellbore),
    SCIENTIFIC (drilling according to Law of Scientific research and exploration),
    STRATIGRAPHIC (driling according to Law of Petroleum activities §2-1).
    APPRAISAL
    Status
    Status for the wellbore. Legal values are:

    BLOWOUT: A blowout has occurred in the well.
    CLOSED: A development wellbore that has been closed in a shorter or longer periode. Also applies to development wellbores where drilling is completed, but production/injection has not yet been reported.
    DRILLING: The well is in the drilling phase - can be active drilling, logging, testing or plugging,
    JUNKED: The drilling operation has been terminated due to technical problems.
    P&A: Exploration: The well is plugged and abandoned, and can not be reentered for further use. Development wells: The production/injection from/to the well is stopped and the well is plugged. The wellhead is removed or else made unavailable for further well operations.
    PLUGGED: The wellbore has been plugged, but the upper parts of the wellbore can be re-used. A sidetrack might be drilled at a later stage.
    PRODUCING: It was produced from the wellbore at the time of the operators last monthly report to the Norwegian Offshore Directorate.
    INJECTING: It was injected to the wellbore at the time of the operators last monthly report to the Norwegian Offshore Directorate.
    PREDRILLED: The upper part of the well has been drilled, usually as part of a batch-drilling campaign covering several wellbores.
    RE-CLASS TO DEV: Exploration wellbore that is reclassified to a development wellbore.
    RE-CLASS TO TEST: Exploration wellbore that is reclassified to test production.
    SUSPENDED: The drilling operation in the wellbore has been temporarily stopped. The current plan is to continue drilling later on.
    P&A
    Factmaps in new window
    Main area
    Name of the area on the Norwegian Continental Shelf where the wellbore is located. Legal values: BARENTS SEA, NORWEGIAN SEA, NORTH SEA.
    NORTH SEA
    Field
    Name of the field the wellbore is related to.
    Discovery
    Name of the discovery the wellbore is related to.
    Well name
    Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    33/9-9
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    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.
    Mobil Exploration Norway INC
    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.
    179-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.
    114
    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,
    27.07.1977
    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.
    17.11.1977
    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.
    17.11.1979
    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.
    03.10.2011
    Purpose - planned
    Pre-drill purpose of the wellbore. Legal values for exploration wellbores: WILDCAT, APPRAISAL, WILDCAT-CCS, APPRAISAL-CCS. Example of legal values for development wellbores: OBSERVATION, PRODUCTION, INJECTION.
    APPRAISAL
    Reentry
    Status whether the wellbore has been re-entered (YES) or not (NO). Re-entered wellbores are not included in the count when wellbores are presented in statistical overviews.
    NO
    Content
    For exploration wellbores, status of discovery.

    Legal values:
    DRY, SHOWS (trace amounts of hydrocarbons), GAS, GAS/CONDENSATE, OIL or OIL/GAS.
    SHOWS (GAS SHOWS, OIL SHOWS or OIL/GAS SHOWS) are detected as fluorescent cut (organic extract), petroleum odour, or visual stain on cuttings or cores, or as increased gas reading on the mud-loggers gas detection equipment.
    Legal values for WILDCAT-CCS and APPRAISAL-CCS: WATER

    For development wellbores, type of produced/injected fluid.
    Legal values:
    WATER, CUTTINGS, NOT AVAILABLE, OIL, GAS/CONDENSATE, OIL/GAS, CO2, GAS, WATER/GAS, NOT APPLICABLE.
    OIL/GAS
    Discovery wellbore
    Indicator which tells if the wellbore made a new discovery. Legal values: YES, NO. Prior to press-release or other information regarding drilling results, the indicator will be “NO” as a default.
    NO
    1st level with HC, age
    Age of lithostratigraphic unit, 1st level, where hydrocarbons were encountered. Examples of legal values: CRETACEOUS, EARLY CRETACEOUS, LATE JURASSIC, EOCENE. See also Norwegian Offshore Directorate bulletins.
    MIDDLE JURASSIC
    1st level with HC, formation
    Name of lithostartigraphic unit, 1st level, where hydrocarbons were encountered. Shown only for released wells. Examples of legal values: BASEMENT, COOK FM, EKOFISK FM, HEIMDAL FM, SANDNES FM, SOGNEFJORD FM, TARBERT FM, BRENT GP. See also Norwegian Offshore Directorate bulletins.
    BRENT GP
    2nd level with HC, age
    Age of lithostratigraphic unit, 2nd level, where hydrocarbons were encountered. Examples of legal values: CRETACEOUS, EARLY CRETACEOUS, LATE JURASSIC, EOCENE.
    EARLY JURASSIC
    2nd level with HC, formation
    Name of lithostartigraphic unit, 2nd level, where hydrocarbons were encountered. Shown only for released wells. Examples of legal values: BASEMENT, COOK FM, EKOFISK FM, HEIMDAL FM, SANDNES FM, SOGNEFJORD FM, TARBERT FM, BRENT GP.
    DUNLIN GP
    3rd level with HC, age
    Age of lithostratigraphic unit, 3rd level, where hydrocarbons were encountered. Examples of legal values: CRETACEOUS, EARLY CRETACEOUS, LATE JURASSIC, EOCENE.
    EARLY JURASSIC
    3rd level with HC, formation
    Name of lithostartigraphic unit, 3rd level, where hydrocarbons were encountered. Shown only for released wells. Examples of legal values: BASEMENT, COOK FM, EKOFISK FM, HEIMDAL FM, SANDNES FM, SOGNEFJORD FM, TARBERT FM, BRENT GP.
    STATFJORD GP
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    25.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    145.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3100.0
    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).
    3098.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    5.2
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    96
    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.
    STATFJORD GP
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    61° 17' 10.19'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    1° 54' 26.05'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6795313.86
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    441428.36
    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.
    414

  • Wellbore history
    General
    Well 33/9-9 was drilled in the northern part of the Statfjord field, about 1.6 km southeast of 33/9-3 well on the Tampen Spur in the northern North Sea. The objectives were to provide structural and stratigraphic control on the Brent reservoirs, and to provide stratigraphic control and to establish an oil/water contact for the Statfjord reservoir.
    Operations and results
    Appraisal well 33/9-9 was spudded with the semi-submersible installation Borgny Dolphin on 27 July 1977 and drilled to TD at 3100 m in Late Triassic sediments in the Statfjord Formation. The well was drilled with seawater down to 486 m and with a seawater/lignosulphonate mud system from 486 m to 1993 m. At 1993 m, TD in the 17 1/2" section, the hole was displaced to a freshwater/Lignosulphonate mud system. At the same point diesel was added to free the 13 3/8" casing which had become differentially stuck. After that the mud contained initially 5% diesel decreasing to traces of diesel at to 2489 m. From 2489 m to final TD the freshwater/Lignosulphonate mud system was without measurable diesel.
    No hydrocarbon shows were reported above the Brent Group. The Brent Group was found at 2413 m, 77.5 m deeper than prognosed 44.0 m thinner than anticipated in comparison to 33/9-3. Good oil shows were encountered at the top of the Brent Formation and continued throughout the reservoir down to top Dunlin Group at 2504 m. The entire Brent Group was oil-filled and it was above the field oil/water contact of 2609.1 m (2584.1 MSL). Log calculations showed that of the 87.0 m of gross oil section 84.6 m was net sand with 27.5% average porosity and 13.1% average water saturation. The Dunlin Group came in at 2504 m and log interpretation indicated a 23.2 m gross oil bearing reservoir between 2528.4 and 2551.6 m with 17.9 m net oil sand. The interval had 20.2% average porosity and 34.6% water saturation. Oil shows were reported from ditch samples and side wall cores in the Dunlin sand between 2535 and 2575 m. No OWC was established in the Dunlin Group. It was assumed that Brent and Dunlin had a common OWC at 2609.1 m (2584.1 MSL), outside well position. The Early Jurassic Statfjord Formation was penetrated at 2715.0, only 5.0 m deep to prognosis confirming that the Statfjord seismic reflector is a reliable mapping horizon. Good oil shows were reported from the top down to about 2850.0 m. The lowest potential pay sand indicated on the CPI log occurs between 2847.5 and 2852.5 m, but a test in this interval, DST No. 2, produced water with only trace oil. The anticipated oil/water contact was not found. The lowest-known-oil in the well at 2815.0 m (2790.0 m MSL) is 13.1 m above the lowest-known-oil previously established in the 33/12-2, which falls within a section of tight sands and shales in 33/9-9.
    A total of 23 cores were cut in the well. Cores no 1 to 8 were taken through the Brent reservoir and into the shaly top of Dunlin, while cores no 9 to 23 were cut in the Statfjord Formation. A significant error in core depth is noted for the first 16 cores. For these 11.3 m must be added to the registered core depths in order to match with the logger's depth. The last seven cores had core-log mismatch within +/- 2 m.
    The well was permanently abandoned on 17 November 1977 as n oil and gas appraisal well.
    Testing
    Six separate zones were successfully tested, requiring a total of nine attempts. The purpose of the tests was to obtain information from six separate zones in the Brent, Dunlin and Statfjord Sands in order to further evaluate the reservoirs. The tests for the first two zones were designed primarily for production data, bottom hole pressures and formation fluid samples, with sustained sand production expected only if very thin unconsolidated sand stringers were present. The last four zones where sand bonding was weak, as calculated from the well log data, had the additional test requirement of measuring the oil rate at which the formation sand broke down.
    DST 1 in the interval 2847.5 to 2852.5 m in the Statfjord Formation was a misrun.
    DST 2 in the interval 2847.5 to 2852.5 m in the Statfjord Formation produced 215 Sm3 water and only trace oil /day through a 3/4" choke. The recorded bottom hole temperature was 91.1 deg C. Sand was produced throughout the test, at rates from 1200 to 300 pounds/thousand barrels (ptb)
    DST 3 in the interval 2800.0 m to 2803.5 m in the Statfjord Formation produced in the final flow period 254 Sm3 oil /day through a 1/4" choke. The GOR was 82 Sm3/Sm3 and the oil gravity was 39.0 deg API. The recorded bottom hole temperature was 86.1 deg C. After the initial cleanup flow no sand was produced.
    DST 4 in the interval 2742.0 m to 2745.0 m in the Statfjord Formation was a misrun.
    DST 5 in the interval 2742.0 m to 2745.0 m in the Statfjord Formation produced in the final flow period 513 Sm3 oil /day through a 5/16" choke. The GOR was 93 Sm3/Sm3 and the oil gravity was 38.7 deg API. The recorded bottom hole temperature was 89.4 deg C. Sand was produced after each rate change (20 ptb), but cleaned up rapidly. Sand began producing more or less continuously, in bursts, on 5/8" choke (40 ptb) indicating formation was breaking down.
    DST 6 in the interval 2742.0 m to 2745.0 m in the Statfjord Formation produced in the final flow period 299 Sm3 oil /day through a 1/4" choke. The GOR was 129 Sm3/Sm3 and the oil gravity was 38.6 deg API. The recorded bottom hole temperature was 89 deg C.No sand was observed other than a few grains upon initial cleanup on 7/16" choke.
    DST 7 in the interval 2531.0 m to 2537.0 m in the Dunlin Group produced in the final flow period 442 Sm3 oil /day through a 23/64" choke. The GOR was 117 Sm3/Sm3 and the oil gravity was 34.4 deg API. The recorded bottom hole temperature was 82.8 deg C. On 1 1/4" choke sand production was observed on a continuous basis at about 120 ptb.
    DST 8 in the interval 2458.0 m to 2460.7 m in the Brent Group produced in the final flow period 525 Sm3 oil /day through a 24/64" choke. The GOR was 144 Sm3/Sm3 and the oil gravity was 37.6 deg API (measured in the first flow period). The recorded bottom hole temperature was 80.1 deg C. Only small amounts of sand were produced.
    DST 9 in the interval 2426.0 m to 2432.8 m in the Brent Group produced in the final flow period 416 Sm3 oil /day through a 22/64" choke. The GOR was 170 Sm3/Sm3 and the oil gravity was 38.5 deg API (measured in the first flow period). No temperature was recorded due to malfunction in the temperature gauge. Small amounts of sand were produced throughout the test. No measurable sand was produced on the highest flow rate (50/64" adjustable choke).

  • 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]
    254.00
    3101.00

  • 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
    2414.0
    2421.9
    [m ]
    2
    2432.3
    2444.3
    [m ]
    3
    2444.3
    2444.8
    [m ]
    4
    2446.3
    2455.3
    [m ]
    5
    2455.3
    2468.3
    [m ]
    6
    2468.3
    2482.3
    [m ]
    7
    2482.3
    2500.6
    [m ]
    8
    2500.6
    2517.8
    [m ]
    9
    2719.0
    2722.3
    [m ]
    10
    2722.3
    2732.3
    [m ]
    11
    2732.3
    2740.3
    [m ]
    12
    2740.3
    2754.8
    [m ]
    13
    2754.8
    2768.6
    [m ]
    14
    2768.8
    2774.3
    [m ]
    15
    2774.3
    2786.6
    [m ]
    16
    2786.6
    2793.0
    [m ]
    17
    2793.0
    2807.5
    [m ]
    18
    2807.5
    2818.4
    [m ]
    19
    2818.4
    2826.2
    [m ]
    20
    2826.2
    2837.5
    [m ]
    21
    2837.5
    2853.5
    [m ]
    22
    2853.5
    2866.0
    [m ]
    23
    2866.0
    2876.5
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    249.2
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 24414-2416m
    Core photo at depth: 2416-2419m
    Core photo at depth: 2419-2421m
    Core photo at depth: 2421-2424m
    Core photo at depth: 2424-2426m
    24414-2416m
    2416-2419m
    2419-2421m
    2421-2424m
    2424-2426m
    Core photo at depth: 2426-2429m
    Core photo at depth: 2429-2432m
    Core photo at depth: 2432-2432m
    Core photo at depth: 2432-2434m
    Core photo at depth: 2434-2437m
    2426-2429m
    2429-2432m
    2432-2432m
    2432-2434m
    2434-2437m
    Core photo at depth: 2437-2439m
    Core photo at depth: 2439-2443m
    Core photo at depth: 2442-2444m
    Core photo at depth: 2444-2446m
    Core photo at depth: 2446-2448m
    2437-2439m
    2439-2443m
    2442-2444m
    2444-2446m
    2446-2448m
    Core photo at depth: 2448-2451m
    Core photo at depth: 2451-2453m
    Core photo at depth: 2453-2455m
    Core photo at depth: 2455-2458m
    Core photo at depth: 2458-2460m
    2448-2451m
    2451-2453m
    2453-2455m
    2455-2458m
    2458-2460m
    Core photo at depth: 2460-2463m
    Core photo at depth: 2463-2465m
    Core photo at depth: 2465-2465m
    Core photo at depth: 2468-2470m
    Core photo at depth: 2470-2473m
    2460-2463m
    2463-2465m
    2465-2465m
    2468-2470m
    2470-2473m
    Core photo at depth: 2473-2475m
    Core photo at depth: 2475-2478m
    Core photo at depth: 2478-2480m
    Core photo at depth: 2480-2481m
    Core photo at depth: 2481-2484m
    2473-2475m
    2475-2478m
    2478-2480m
    2480-2481m
    2481-2484m
    Core photo at depth: 2484-2487m
    Core photo at depth: 2487-2490m
    Core photo at depth: 2490-2492m
    Core photo at depth: 2492-2495m
    Core photo at depth: 2495-2498m
    2484-2487m
    2487-2490m
    2490-2492m
    2492-2495m
    2495-2498m
    Core photo at depth: 2498-2500m
    Core photo at depth: 2500-2503m
    Core photo at depth: 2503-2505m
    Core photo at depth: 2505-2508m
    Core photo at depth: 2508-2522m
    2498-2500m
    2500-2503m
    2503-2505m
    2505-2508m
    2508-2522m
    Core photo at depth: 2511-2513m
    Core photo at depth: 2513-2516m
    Core photo at depth: 2516-2516m
    Core photo at depth: 2719-2722m
    Core photo at depth: 2722-2725m
    2511-2513m
    2513-2516m
    2516-2516m
    2719-2722m
    2722-2725m
    Core photo at depth: 2725-2727m
    Core photo at depth: 2727-2732m
    Core photo at depth: 2732-2734m
    Core photo at depth: 2734-2737m
    Core photo at depth: 2737-2740m
    2725-2727m
    2727-2732m
    2732-2734m
    2734-2737m
    2737-2740m
    Core photo at depth: 2740-2742m
    Core photo at depth: 2742-2745m
    Core photo at depth: 2742-2745m
    Core photo at depth: 2745-2748m
    Core photo at depth: 2748-2750m
    2740-2742m
    2742-2745m
    2742-2745m
    2745-2748m
    2748-2750m
    Core photo at depth: 2750-2754m
    Core photo at depth: 2754-2757m
    Core photo at depth: 2757-2760m
    Core photo at depth: 2760-2762m
    Core photo at depth: 2762-2765m
    2750-2754m
    2754-2757m
    2757-2760m
    2760-2762m
    2762-2765m
    Core photo at depth: 2765-2768m
    Core photo at depth: 2768-2774m
    Core photo at depth: 2774-2776m
    Core photo at depth: 2776-2779m
    Core photo at depth: 2779-2782m
    2765-2768m
    2768-2774m
    2774-2776m
    2776-2779m
    2779-2782m
    Core photo at depth: 2782-2784m
    Core photo at depth: 2784-2786m
    Core photo at depth: 2786-2789m
    Core photo at depth: 2789-2791m
    Core photo at depth: 2791-2793m
    2782-2784m
    2784-2786m
    2786-2789m
    2789-2791m
    2791-2793m
    Core photo at depth: 2793-2795m
    Core photo at depth: 2795-2798m
    Core photo at depth: 2798-2807m
    Core photo at depth: 2807-2810m
    Core photo at depth: 2810-2812m
    2793-2795m
    2795-2798m
    2798-2807m
    2807-2810m
    2810-2812m
    Core photo at depth: 2812-2815m
    Core photo at depth: 2815-2818m
    Core photo at depth: 2818-2821m
    Core photo at depth: 2821-2823m
    Core photo at depth: 2823-2826m
    2812-2815m
    2815-2818m
    2818-2821m
    2821-2823m
    2823-2826m
    Core photo at depth: 2826-2828m
    Core photo at depth: 2828-2831m
    Core photo at depth: 2831-2834m
    Core photo at depth: 2834-2837m
    Core photo at depth: 2837-2840m
    2826-2828m
    2828-2831m
    2831-2834m
    2834-2837m
    2837-2840m
    Core photo at depth: 2840-2842m
    Core photo at depth: 2842-2845m
    Core photo at depth: 2845-2847m
    Core photo at depth: 2847-2850m
    Core photo at depth: 2850-2853m
    2840-2842m
    2842-2845m
    2845-2847m
    2847-2850m
    2850-2853m
    Core photo at depth: 2853-2856m
    Core photo at depth: 2856-2858m
    Core photo at depth: 2861-2863m
    Core photo at depth: 2863-2866m
    Core photo at depth: 2866-2868m
    2853-2856m
    2856-2858m
    2861-2863m
    2863-2866m
    2866-2868m
    Core photo at depth: 2868-2871m
    Core photo at depth: 2871-2874m
    Core photo at depth: 2874-2876m
    Core photo at depth: 2858-2861m
    Core photo at depth:  
    2868-2871m
    2871-2874m
    2874-2876m
    2858-2861m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    2420.3
    [m]
    C
    LAP
    2420.3
    [m]
    C
    OD
    2431.1
    [m]
    C
    OD
    2431.1
    [m]
    C
    LAP
    2433.8
    [m]
    C
    LAP
    2433.8
    [m]
    C
    OD
    2434.4
    [m]
    C
    OD
    2434.4
    [m]
    C
    LAP
    2436.1
    [m]
    C
    LAP
    2436.1
    [m]
    C
    OD
    2436.5
    [m]
    C
    OD
    2436.5
    [m]
    C
    LAP
    2437.2
    [m]
    C
    LAP
    2437.2
    [m]
    C
    OD
    2437.8
    [m]
    C
    OD
    2437.8
    [m]
    C
    LAP
    2438.6
    [m]
    C
    LAP
    2438.6
    [m]
    C
    OD
    2438.7
    [m]
    C
    OD
    2438.7
    [m]
    C
    LAP
    2440.9
    [m]
    C
    LAP
    2440.9
    [m]
    C
    OD
    2442.8
    [m]
    C
    OD
    2442.8
    [m]
    C
    LAP
    2443.0
    [m]
    C
    LAP
    2443.0
    [m]
    C
    OD
    2443.0
    [m]
    C
    OD
    2443.0
    [m]
    C
    LAP
    2443.5
    [m]
    C
    LAP
    2443.5
    [m]
    C
    OD
    2444.5
    [m]
    C
    OD
    2444.5
    [m]
    C
    LAP
    2446.3
    [m]
    C
    LAP
    2446.3
    [m]
    C
    OD
    2446.9
    [m]
    C
    LAP
    2448.6
    [m]
    C
    LAP
    2448.6
    [m]
    C
    OD
    2448.8
    [m]
    C
    OD
    2448.8
    [m]
    C
    LAP
    2448.9
    [m]
    C
    LAP
    2448.9
    [m]
    C
    OD
    2450.3
    [m]
    C
    OD
    2450.3
    [m]
    C
    LAP
    2451.8
    [m]
    C
    LAP
    2451.8
    [m]
    C
    OD
    2453.3
    [m]
    C
    OD
    2453.3
    [m]
    C
    LAP
    2455.0
    [m]
    C
    LAP
    2455.0
    [m]
    C
    OD
    2455.3
    [m]
    C
    OD
    2455.3
    [m]
    C
    LAP
    2456.6
    [m]
    C
    LAP
    2456.6
    [m]
    C
    OD
    2459.3
    [m]
    C
    OD
    2459.3
    [m]
    C
    LAP
    2469.3
    [m]
    C
    LAP
    2469.3
    [m]
    C
    OD
    2486.0
    [m]
    C
    LAP
    2489.0
    [m]
    C
    LAP
    2494.0
    [m]
    C
    LAP
    2497.0
    [m]
    C
    LAP
    2500.0
    [m]
    C
    LAP
    2502.0
    [m]
    C
    LAP
    2503.0
    [m]
    C
    LAP
    2504.0
    [m]
    C
    LAP
    2507.0
    [m]
    C
    LAP
    2512.0
    [m]
    C
    LAP
    2516.0
    [m]
    C
    LAP

  • Lithostratigraphy
    Lithostratigraphy
    Top depth [mMD RKB]
    Lithostrat. unit
    170
    997
    1660
    1660
    1693
    1848
    2396
    2413
    2504
    2504
    2528
    2558
    2715

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    1.24

  • 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
    2.47
    pdf
    0.98
    pdf
    2.33
    pdf
    1.80
    pdf
    2.95
    pdf
    0.82
    pdf
    10.65
    pdf
    6.73
    pdf
    1.31
    pdf
    2.95
    pdf
    0.59
    pdf
    0.53
    pdf
    0.87
    pdf
    10.47
    pdf
    12.44
    pdf
    3.03
    pdf
    6.89
    pdf
    1.64
    pdf
    0.13
    pdf
    3.67

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    2.0
    2848
    2853
    19.0
    3.0
    2800
    2804
    19.0
    5.0
    2742
    2745
    15.9
    6.0
    2742
    2745
    11.0
    7.0
    2531
    2538
    30.0
    8.0
    2458
    2461
    19.0
    9.0
    2426
    2433
    0.0
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    2.0
    3.0
    30.000
    5.0
    34.000
    6.0
    38.000
    89
    7.0
    24.000
    8.0
    34.000
    9.0
    Drill stem tests (DST)
    Test number
    Oil
    [Sm3/day]
    Gas
    [Sm3/day]
    Oil density
    [g/cm3]
    Gas grav. rel.air
    GOR
    [m3/m3]
    2.0
    3.0
    1438
    0.830
    412
    5.0
    1206
    0.830
    545
    6.0
    863
    0.830
    618
    7.0
    1327
    0.830
    569
    8.0
    1468
    0.830
    1059
    9.0

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    DLL
    2350
    3100
    FDC CNL
    475
    3100
    GR SPECTRO
    2350
    3100
    HDT
    2300
    3100
    ISF SONIC
    245
    3100
    LS SONIC
    1990
    3098
    RFT
    0
    0
    VSP
    355
    2955

  • 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
    244.0
    36
    249.0
    0.00
    LOT
    SURF.COND.
    20
    475.0
    26
    486.0
    0.00
    LOT
    INTERM.
    13 3/8
    1984.0
    17 1/2
    1993.0
    0.00
    LOT
    INTERM.
    9 5/8
    3068.0
    12 1/4
    3100.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    249
    1.07
    waterbased
    760
    1.14
    waterbased
    1137
    1.16
    waterbased
    1568
    1.25
    waterbased
    1993
    1.37
    waterbased
    2421
    1.72
    waterbased

  • Thin sections at the Norwegian Offshore Directorate
    Thin sections at the Norwegian Offshore Directorate
    Depth
    Unit
    2748.45
    [m ]
    2751.45
    [m ]
    2756.30
    [m ]
    2759.20
    [m ]
    2764.55
    [m ]
    2765.88
    [m ]
    2782.55
    [m ]
    2799.60
    [m ]
    2809.30
    [m ]
    2722.85
    [m ]

  • 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
    0.22