Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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22.07.2024 - 01:26
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30/2-2

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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.
    30/2-2
    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).
    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.
    30/2-2
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    L 8330 - 134 SP. 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.
    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.
    447-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.
    137
    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,
    19.12.1984
    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.
    04.05.1985
    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.
    04.05.1987
    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.
    18.02.2015
    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.
    GAS/CONDENSATE
    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
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    29.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    123.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4172.0
    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).
    4169.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    7.8
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    152
    Oldest penetrated age
    Age (according to Geologic Time Scale 2004 by F. M. Gradstein, et al. (2004)) of the oldest penetrated formation. May differ from age at TD for example in deviated wellbores. Examples of legal values: CRETACEOUS, EARLY CRETACEOUS, LATE JURASSIC, EARLY PERMIAN, EARLY TRIASSIC, EOCENE.
    EARLY JURASSIC
    Oldest penetrated formation
    Name of the oldest lithostratigraphic unit penetrated by the wellbore. Shown only for released wells. In most wellbores this is formation or group at total depth. May differ from formation or group at TD for example in wellbores drilled with high deviation or through faults. Examples of legal values: AMUNDSEN FM, BALDER FM, BASEMENT, BLODØKS FM, BRYNE FM, BURTON FM, COOK FM, DRAKE FM, DRAUPNE FM, EKOFISK FM, DUNLIN GP.
    DRAKE FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    60° 49' 53.89'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 39' 51.65'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6744240.64
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    481749.07
    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.
    457
  • Wellbore history

    General
    Well 30/2-2 was drilled on the Mokkukalven Fault Complex north of the Oseberg Field in the North Sea. The objective was to test possible hydrocarbon accumulations in the Huldra Field, on a structural high that is separated from Huldra discovery well 30/2-1 with significant faults. Well 30/2-1 encountered a 119 m gas column in the Brent Group with a down-to contact at 3793 m. The actual gas/water or oil/water contact could not be established. The main target for 30/2-2 was the Brent Group, believed to be some 70 m deeper than the gas column in 30/2-1.
    Operations and results
    Appraisal well 30/2-2 was spudded with the semi-submersible installation Dyvi Delta on 19 December 1984 and drilled to TD at 4172 m in the Early Jurassic Drake Formation. When doing the reservoir logging, a radioactive part of the logging tool was left in the hole. This accident caused a sidetrack from 3894 m KB to TD. The sidetrack ran parallel to the original hole at a distance of approximately 20 m. The intention was to drill 50 m into the Statfjord Formation, but the well was finished in the Drake Formation due to hole conditions. The well was drilled with spud mud down to 214 m, with gel/seawater from 214 m to 1023 m, with gypsum/CMC mud from 1023 m to 3802 m, and with gel/lignosulphonate from 3802 m to TD.
    Gas bearing Brent sandstone was encountered at 3935 m, with the gas-water contact somewhere in the interval 3975 - 4080 m. No distinct contact was possible to recognize from logs or shows, but later geochemical analyses of the corers indicated a contact at ca 3984 m. Fluorescence indicating shows was first recorded on claystone/limestone cuttings in the interval 2204 m to 2267 m in the Lista Formation. Intermittent golden cut was observed on cuttings samples in the interval 2489 m to 2585 m in the Shetland Group. Otherwise, oil/condensate shows were recorded on sandstones from the Brent Group through the hydrocarbon-bearing reservoir. Below the contact, weak shows believed to relate to in-situ kerogen in coals and shales were recorded down to TD.
    A total of 157 m conventional core was recovered in eighteen cores in the interval from 3908 m in the lower Heather Formation, through all of Brent Group and down to 4139.1 m in the uppermost Drake Formation. All cores were cut in the original hole, before side-tracking. Log runs 1 to 5 were also run in the original hole, while run 6 and 7 were run in the sidetrack. No wire line fluid samples were taken.
    The well was permanently abandoned on 4 May 1985 as a gas appraisal well.
    Testing
    Three drill stem tests were conducted in the Brent Group.
    DST 1B tested the interval 4071 - 4076 m in the Etive Formation. The test flowed water at only five m3/day through a 19.05 mm choke during a 7.07 hours flow period. The maximum temperature reading was 150 °C. DST 1A failed due to technical problems.
    DST 2B tested the intervals 4011-4013 m, 4017-4025 m, and 4035 - 4042 m in the Ness Formation. The test flowed water at only eight m3/day through a 19.05 mm choke during a 13.5 hours flow period. The maximum temperature reading was 148 °C. DST 2A failed due to technical problems.
    DST 3 tested the intervals 3935 - 3949 m, 3955 – 3959 m, and 3967-3974 m in the Tarbert Formation. It produced 227600 Sm3 gas and 105 Sm3 condensate /day through a 19.05 mm choke. The GOR was 2170 Sm3/Sm3. The maximum temperature reading was 137 °C.
  • Cuttings at the Norwegian Offshore Directorate

    Cuttings at the Norwegian Offshore Directorate
    Cuttings available for sampling?
    NO
    Cuttings at the Norwegian Offshore Directorate
    Cutting sample, top depth [m]
    Cutting samples, bottom depth [m]
    220.00
    4172.00
  • 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
    3908.0
    3912.5
    [m ]
    2
    3939.0
    3957.3
    [m ]
    3
    3957.3
    3965.8
    [m ]
    4
    3966.0
    3979.8
    [m ]
    5
    3979.8
    3987.6
    [m ]
    6
    3987.8
    3989.6
    [m ]
    7
    3989.6
    3993.5
    [m ]
    8
    3993.5
    3997.5
    [m ]
    9
    4014.0
    4025.6
    [m ]
    10
    4026.0
    4027.9
    [m ]
    11
    4029.0
    4031.6
    [m ]
    12
    4031.8
    4047.7
    [m ]
    13
    4047.7
    4048.9
    [m ]
    14
    4048.9
    4052.5
    [m ]
    15
    4076.0
    4093.8
    [m ]
    16
    4094.0
    4112.3
    [m ]
    17
    4112.3
    4130.3
    [m ]
    18
    4130.5
    4135.5
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    158.4
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES
  • Core photos

    Core photos
    Core photo at depth: 3908-3912m
    Core photo at depth: 3939-3944m
    Core photo at depth: 3944-3950m
    Core photo at depth: 3950-3956m
    Core photo at depth: 3956-3957m
    3908-3912m
    3939-3944m
    3944-3950m
    3950-3956m
    3956-3957m
    Core photo at depth: 3957-3963m
    Core photo at depth: 3963-3965m
    Core photo at depth: 3966-3972m
    Core photo at depth: 3972-3978m
    Core photo at depth: 3978-3979m
    3957-3963m
    3963-3965m
    3966-3972m
    3972-3978m
    3978-3979m
    Core photo at depth: 3979-3985m
    Core photo at depth: 3985-3987m
    Core photo at depth: 3987-3989m
    Core photo at depth: 3989-3993m
    Core photo at depth: 3993-3997m
    3979-3985m
    3985-3987m
    3987-3989m
    3989-3993m
    3993-3997m
    Core photo at depth: 4014-4020m
    Core photo at depth: 4020-4025m
    Core photo at depth: 4026-4027m
    Core photo at depth: 4029-4031m
    Core photo at depth: 4031-4037m
    4014-4020m
    4020-4025m
    4026-4027m
    4029-4031m
    4031-4037m
    Core photo at depth: 4037-4043m
    Core photo at depth: 4043-4047m
    Core photo at depth: 4047-4048m
    Core photo at depth: 4048-4052m
    Core photo at depth: 4076-4082m
    4037-4043m
    4043-4047m
    4047-4048m
    4048-4052m
    4076-4082m
    Core photo at depth: 4082-4088m
    Core photo at depth: 4088-4093m
    Core photo at depth: 4094-4100m
    Core photo at depth: 4100-4106m
    Core photo at depth: 4106-4112m
    4082-4088m
    4088-4093m
    4094-4100m
    4100-4106m
    4106-4112m
    Core photo at depth: 4112-4112m
    Core photo at depth: 4112-4118m
    Core photo at depth: 4118-4124m
    Core photo at depth: 4124-4130m
    Core photo at depth: 4130-4130m
    4112-4112m
    4112-4118m
    4118-4124m
    4124-4130m
    4130-4130m
    Core photo at depth: 4130-4135m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    4130-4135m
  • Palynological slides at the Norwegian Offshore Directorate

    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    2000.0
    [m]
    C
    GEOST
    2018.0
    [m]
    C
    GEOST
    2030.0
    [m]
    C
    GEOST
    2048.0
    [m]
    C
    GEOST
    2060.0
    [m]
    C
    GEOST
    2078.0
    [m]
    C
    GEOST
    2090.0
    [m]
    C
    GEOST
    2108.0
    [m]
    C
    GEOST
    2120.0
    [m]
    C
    GEOST
    2138.0
    [m]
    C
    GEOST
    2150.0
    [m]
    C
    GEOST
    2168.0
    [m]
    C
    GEOST
    2180.0
    [m]
    C
    GEOST
    2198.0
    [m]
    C
    GEOST
    2210.0
    [m]
    C
    GEOST
    2228.0
    [m]
    C
    GEOST
    2240.0
    [m]
    C
    GEOST
    2264.0
    [m]
    C
    GEOST
    2270.0
    [m]
    C
    GEOST
    2288.0
    [m]
    C
    GEOST
    2300.0
    [m]
    C
    GEOST
    2318.0
    [m]
    C
    GEOST
    2330.0
    [m]
    C
    GEOST
    2348.0
    [m]
    C
    GEOST
    2360.0
    [m]
    C
    GEOST
    2378.0
    [m]
    C
    GEOST
    2390.0
    [m]
    C
    GEOST
    2408.0
    [m]
    C
    GEOST
    2420.0
    [m]
    C
    GEOST
    2438.0
    [m]
    C
    GEOST
    2450.0
    [m]
    C
    GEOST
    2468.0
    [m]
    C
    GEOST
    2480.0
    [m]
    C
    GEOST
    2496.0
    [m]
    C
    GEOST
    2518.0
    [m]
    C
    GEOST
    2528.0
    [m]
    C
    GEOST
    2542.0
    [m]
    C
    GEOST
    2558.0
    [m]
    C
    GOEST
    2570.0
    [m]
    C
    GEOST
    2585.0
    [m]
    C
    GEOST
    2600.0
    [m]
    C
    GEOST
    2618.0
    [m]
    C
    GEOST
    2630.0
    [m]
    C
    GEOST
    2648.0
    [m]
    C
    GEOST
    2660.0
    [m]
    C
    GEOST
    2678.0
    [m]
    C
    GEOST
    2690.0
    [m]
    C
    GEOST
    2708.0
    [m]
    C
    GEOST
    2720.0
    [m]
    DC
    GEOST
    2738.0
    [m]
    C
    GEOST
    2750.0
    [m]
    C
    GEOST
    2753.0
    [m]
    C
    GEOST
    2768.0
    [m]
    C
    GEOST
    2780.0
    [m]
    C
    GEOST
    2798.0
    [m]
    C
    GEOST
    2810.0
    [m]
    C
    GEOST
    2828.0
    [m]
    C
    GEOST
    2840.0
    [m]
    C
    GEOST
    2858.0
    [m]
    C
    GEOST
    2870.0
    [m]
    C
    GEOST
    2888.0
    [m]
    C
    GEOST
    2900.0
    [m]
    C
    GEOST
    2918.0
    [m]
    C
    GEOST
    2930.0
    [m]
    C
    GEOST
    2948.0
    [m]
    C
    GEOST
    2960.0
    [m]
    DC
    GEOST
    2978.0
    [m]
    C
    GEOST
    2990.0
    [m]
    C
    GEOST
    3008.0
    [m]
    C
    GEOST
    3020.0
    [m]
    C
    GEOST
    3038.0
    [m]
    C
    GEOST
    3068.0
    [m]
    C
    GEOST
    3080.0
    [m]
    C
    GEOST
    3098.0
    [m]
    C
    GEOST
    3110.0
    [m]
    C
    GEOST
    3128.0
    [m]
    C
    GEOST
    3140.0
    [m]
    C
    GEOST
    3158.0
    [m]
    C
    GEOST
    3170.0
    [m]
    C
    GEOST
    3188.0
    [m]
    C
    GEOST
    3200.0
    [m]
    C
    GEOST
    3230.0
    [m]
    C
    GEOST
    3248.0
    [m]
    C
    GEOST
    3260.0
    [m]
    C
    GEOST
    3278.0
    [m]
    C
    GEOST
    3290.0
    [m]
    C
    GEOST
    3308.0
    [m]
    C
    GEOST
    3320.0
    [m]
    C
    GEOST
    3338.0
    [m]
    C
    GEOST
    3350.0
    [m]
    C
    GEOST
    3368.0
    [m]
    C
    GEOST
    3380.0
    [m]
    C
    GEOST
    3398.0
    [m]
    C
    GEOST
    3410.0
    [m]
    C
    GEOST
    3428.0
    [m]
    C
    GEOST
    3440.0
    [m]
    C
    GEOST
    3458.0
    [m]
    C
    GEOST
    3470.0
    [m]
    C
    GEOST
    3488.0
    [m]
    C
    GEOST
    3500.0
    [m]
    C
    GEOST
    3518.0
    [m]
    C
    GEOST
    3530.0
    [m]
    C
    GEOST
    3548.0
    [m]
    C
    GEOST
    3560.0
    [m]
    C
    GEOST
    3578.0
    [m]
    C
    GEOST
    3590.0
    [m]
    C
    GEOST
    3608.0
    [m]
    C
    GEOST
    3620.0
    [m]
    C
    GEOST
    3638.0
    [m]
    C
    GEOST
    3650.0
    [m]
    C
    GEOST
    3668.0
    [m]
    C
    GEOST
    3680.0
    [m]
    C
    GEOST
    3698.0
    [m]
    C
    GEOST
    3710.0
    [m]
    C
    GEOST
    3728.0
    [m]
    C
    GEOST
    3740.0
    [m]
    C
    GEOST
    3758.0
    [m]
    C
    GEOST
    3761.0
    [m]
    C
    GEOST
    3770.0
    [m]
    C
    GEOST
    3788.0
    [m]
    C
    GEOST
    3800.0
    [m]
    C
    GEOST
    3818.0
    [m]
    C
    GEOST
    3830.0
    [m]
    C
    GEOST
    3839.0
    [m]
    C
    GEOST
    3848.0
    [m]
    C
    GEOST
    3860.0
    [m]
    C
    GEOST
    3869.0
    [m]
    C
    GEOST
    3878.0
    [m]
    C
    GEOST
    3890.0
    [m]
    C
    GEOST
    3899.0
    [m]
    C
    GEOST
    3908.0
    [m]
    C
    GEOST
    3920.0
    [m]
    C
    GEOST
    3938.0
    [m]
    C
    GEOST
    3940.0
    [m]
    C
    GEOST
    3944.0
    [m]
    SWC
    GEOST
    3950.0
    [m]
    DC
    GEOST
    3953.0
    [m]
    C
    GEOST
    3956.0
    [m]
    C
    GEOST
    3956.0
    [m]
    DC
    GEOST
    3964.0
    [m]
    C
    GEOST
    3968.0
    [m]
    DC
    GEOST
    3970.0
    [m]
    C
    GEOST
    3975.0
    [m]
    C
    GEOST
    3976.0
    [m]
    C
    GEOST
    3977.0
    [m]
    DC
    GEOST
    3978.0
    [m]
    C
    GEOST
    3980.0
    [m]
    DC
    GEOST
    3980.0
    [m]
    C
    GEOST
    3983.0
    [m]
    C
    GEOST
    3985.0
    [m]
    DC
    GEOST
    3990.0
    [m]
    DC
    GEOST
    3994.0
    [m]
    DC
    GEOST
    3995.0
    [m]
    SWC
    GEOST
    3998.0
    [m]
    DC
    GEOST
    4004.0
    [m]
    SWC
    GEOST
    4010.0
    [m]
    DC
    GEOST
    4014.0
    [m]
    C
    GEOST
    4018.0
    [m]
    C
    GEOST
    4024.0
    [m]
    C
    GEOST
    4027.0
    [m]
    C
    GEOST
    4028.0
    [m]
    DC
    GEOST
    4029.0
    [m]
    DC
    GEOST
    4030.0
    [m]
    C
    GEOST
    4036.0
    [m]
    C
    GEOST
    4040.0
    [m]
    DC
    GEOST
    4040.0
    [m]
    C
    GEOST
    4043.0
    [m]
    C
    GEOST
    4044.0
    [m]
    DC
    GEOST
    4046.0
    [m]
    DC
    GEOST
    4047.0
    [m]
    DC
    GEOST
    4048.0
    [m]
    DC
    GEOST
    4048.0
    [m]
    C
    GEOST
    4049.0
    [m]
    C
    GEOST
    4051.0
    [m]
    DC
    GEOST
    4051.0
    [m]
    C
    GEOST
    4052.0
    [m]
    C
    GEOST
    4058.0
    [m]
    DC
    GEOST
    4061.0
    [m]
    SWC
    GEOST
    4070.0
    [m]
    SWC
    GEOST
    4070.0
    [m]
    DC
    GEOST
    4079.0
    [m]
    SWC
    GEOST
    4088.0
    [m]
    DC
    GEOST
    4089.0
    [m]
    C
    GEOST
    4093.0
    [m]
    DC
    GEOST
    4093.0
    [m]
    C
    GEOST
    4095.0
    [m]
    DC
    GEOST
    4096.0
    [m]
    DC
    GEOST
    4097.0
    [m]
    C
    GEOST
    4098.0
    [m]
    C
    GEOST
    4100.0
    [m]
    DC
    GEOST
    4106.0
    [m]
    SWC
    GEOST
    4115.0
    [m]
    SWC
    GEOST
    4118.0
    [m]
    SWC
    GEOST
    4118.0
    [m]
    DC
    GEOST
    4126.0
    [m]
    DC
    GEOST
    4128.0
    [m]
    C
    GEOST
    4130.0
    [m]
    DC
    GEOST
    4132.0
    [m]
    C
    GEOST
    4134.0
    [m]
    C
    GEOST
    4135.0
    [m]
    DC
    GEOST
    4148.0
    [m]
    DC
    GEOST
    4160.0
    [m]
    DC
    GEOST
    4172.0
    [m]
    DC
    GEOST
  • 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
    TEST3
    3935.00
    3974.00
    23.04.1985 - 00:00
    YES
  • Lithostratigraphy

  • Geochemical information

    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.63
    pdf
    3.83
    pdf
    1.71
    pdf
    2.47
    pdf
    0.41
    pdf
    0.10
    pdf
    0.32
    pdf
    0.46
  • 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
    5.09
    pdf
    29.56
  • Drill stem tests (DST)

    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    4071
    4076
    19.1
    2.0
    4011
    4042
    19.1
    3.0
    3935
    3974
    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
    3.0
    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
    2.0
    3.0
    105
    226000
    0.808
    0.734
    2160
  • Logs

    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL
    722
    2345
    CBL
    2425
    3788
    CBL
    3600
    4127
    CDL CNS GR
    214
    4163
    DIL BCS CAL GR
    214
    4164
    DLL MSF GR
    1006
    2718
    FED
    2345
    2716
    NGT
    3665
    4175
    SFT
    3937
    4100
    VELOCITY
    800
    4125
  • 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
    214.5
    36
    214.5
    0.00
    LOT
    SURF.COND.
    20
    1008.0
    26
    1023.0
    1.61
    LOT
    INTERM.
    13 3/8
    2350.0
    17 1/2
    2365.0
    2.03
    LOT
    INTERM.
    9 5/8
    3778.0
    12 1/4
    3802.0
    2.14
    LOT
    LINER
    7
    4170.0
    8 1/2
    4170.0
    0.00
    LOT
  • Drilling mud

    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    1670
    1.11
    9.0
    7.3
    WATERBASED
    04.01.1985
    1670
    1.11
    9.0
    7.3
    WATER BASED
    04.01.1985
    1870
    1.25
    9.0
    10.0
    WATER BASED
    07.01.1985
    1870
    1.25
    9.0
    10.0
    WATERBASED
    07.01.1985
    1978
    1.35
    10.0
    13.0
    WATER BASED
    07.01.1985
    1978
    1.35
    10.0
    13.0
    WATERBASED
    07.01.1985
    2122
    1.45
    15.0
    15.2
    WATER BASED
    07.01.1985
    2122
    1.45
    15.0
    15.2
    WATERBASED
    07.01.1985
    2258
    1.45
    16.0
    8.3
    WATERBASED
    07.01.1985
    2258
    1.45
    16.0
    8.3
    WATER BASED
    07.01.1985
    2365
    1.50
    16.0
    8.4
    WATER BASED
    09.01.1985
    2365
    1.53
    17.0
    8.9
    WATER BASED
    09.01.1985
    2365
    1.55
    16.0
    7.0
    WATER BASED
    14.01.1985
    2365
    1.50
    16.0
    8.4
    WATERBASED
    09.01.1985
    2365
    0.00
    17.0
    8.9
    WATERBASED
    09.01.1985
    2365
    0.00
    16.0
    7.0
    WATERBASED
    14.01.1985
    2472
    1.55
    18.0
    7.4
    WATERBASED
    14.01.1985
    2472
    1.55
    18.0
    7.4
    WATER BASED
    14.01.1985
    2533
    1.60
    20.0
    7.9
    WATER BASED
    15.01.1985
    2533
    1.60
    20.0
    7.9
    WATERBASED
    15.01.1985
    2556
    1.70
    21.0
    7.4
    WATERBASED
    15.01.1985
    2556
    1.70
    21.0
    7.4
    WATER BASED
    15.01.1985
    2605
    1.70
    22.0
    7.9
    WATER BASED
    16.01.1985
    2605
    1.70
    22.0
    7.9
    WATERBASED
    16.01.1985
    2619
    1.73
    22.0
    7.4
    WATER BASED
    16.01.1985
    2619
    1.73
    22.0
    7.4
    WATERBASED
    16.01.1985
    2704
    1.77
    22.0
    7.0
    WATERBASED
    17.01.1985
    2704
    1.77
    22.0
    7.0
    WATER BASED
    17.01.1985
    2802
    1.75
    19.0
    7.0
    WATER BASED
    18.01.1985
    2802
    1.75
    19.0
    7.0
    WATERBASED
    18.01.1985
    2909
    1.78
    22.0
    8.0
    WATERBASED
    21.01.1985
    2909
    1.78
    22.0
    8.0
    WATER BASED
    21.01.1985
    2980
    1.79
    22.0
    8.0
    WATERBASED
    28.01.1985
    2980
    1.79
    22.0
    8.0
    WATER BASED
    28.01.1985
    3802
    1.82
    22.0
    6.0
    WATERBASED
    11.02.1985
    3802
    1.82
    22.0
    6.0
    WATER BASED
    11.02.1985
    3884
    1.91
    25.0
    8.0
    WATER BASED
    18.02.1985
    3884
    1.91
    25.0
    8.0
    WATERBASED
    18.02.1985
    3938
    1.96
    35.0
    8.0
    WATER BASED
    01.04.1985
    3938
    1.96
    35.0
    8.0
    WATERBASED
    01.04.1985
    3950
    1.96
    35.0
    8.0
    WATERBASED
    01.04.1985
    3950
    1.96
    35.0
    8.0
    WATER BASED
    01.04.1985
    4013
    1.94
    26.0
    8.8
    WATERBASED
    26.02.1985
    4013
    1.94
    26.0
    8.8
    WATER BASED
    26.02.1985
    4019
    1.96
    35.0
    8.0
    WATER BASED
    01.04.1985
    4019
    1.96
    35.0
    8.0
    WATERBASED
    01.04.1985
    4100
    1.96
    35.0
    8.0
    WATERBASED
    01.04.1985
    4100
    1.96
    35.0
    8.0
    WATER BASED
    01.04.1985
    4172
    1.96
    35.0
    8.4
    WATER BASED
    26.03.1985
    4172
    1.96
    35.0
    8.4
    WATERBASED
    26.03.1985
    4174
    1.94
    26.0
    8.8
    WATER BASED
    06.03.1985
    4174
    1.94
    26.0
    8.8
    WATERBASED
    06.03.1985
  • Thin sections at the Norwegian Offshore Directorate

    Thin sections at the Norwegian Offshore Directorate
    Depth
    Unit
    4134.68
    [m ]
    4132.38
    [m ]
    4124.70
    [m ]
    4106.35
    [m ]
    4106.02
    [m ]
    4098.90
    [m ]
    4093.30
    [m ]
    4089.65
    [m ]
    4086.65
    [m ]
    4082.65
    [m ]
    4078.65
    [m ]
    4040.25
    [m ]
    4020.73
    [m ]
    3984.42
    [m ]
    3973.67
    [m ]
    3968.45
    [m ]
    4116.65
    [m ]
    3963.74
    [m ]
    3957.82
    [m ]
    3955.70
    [m ]
    3951.45
    [m ]
    3944.90
    [m ]
    3939.95
    [m ]
    4022.30
    [m ]
    3945.00
    [m ]
    4102.00
    [m ]
    3974.90
    [m ]
    3949.40
    [m ]
    4042.90
    [m ]
    4079.40
    [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
    0.21