Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
04.11.2024 - 01:25
Time of last synchronization with Norwegian Offshore Directorate's internal systems

6507/2-2

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.
    6507/2-2
    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).
    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.
    6507/2-2
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    NH 9010 - 102 & SP 565
    Production licence
    Official designation of the production licence the wellbore was drilled or planned to be drilled from ( well head posistion).
    Drilling operator
    Name of the licensee starting the drilling operation on behalf of the active production license (well head position). This will usually equal the operator of the production license.
    Norsk Hydro Produksjon AS
    Drill permit
    The drilling permit number together with the version of the drilling permit as stated in the drilling permit granted by the Norwegian Offshore Directorate.
    702-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.
    148
    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,
    21.10.1991
    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.
    16.03.1992
    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.
    16.03.1994
    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.
    19.12.2007
    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.
    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.
    YES
    1st level with HC, age
    Age of lithostratigraphic unit, 1st level, where hydrocarbons were encountered. Examples of legal values: CRETACEOUS, EARLY CRETACEOUS, LATE JURASSIC, EOCENE. See also Norwegian Offshore Directorate bulletins.
    LATE CRETACEOUS
    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.
    LYSING 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.
    LATE CRETACEOUS
    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.
    LANGE FM
    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.
    384.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3958.0
    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).
    3953.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    10
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    141
    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.
    ÅRE FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    65° 55' 1.69'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    7° 30' 54.56'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7311658.69
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    432391.00
    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.
    1840

  • Wellbore history
    General
    The Dønna Terrace forms a large down faulted block on the western margin of the Trøndelag Platform, situated between the Nordland Ridge and the Vøring Basin. The structure to be tested by 6507/2-2 is situated on the western edge of the Dønna Terrace. This structure was earlier tested by well 6507/2-1, which however left a considerable untested column up-dip from the well position. The main target of the well was the Jurassic reservoirs of Garn, Ile, and Tilje Formation. The secondary objectives were to test the prospectivity of the Cretaceous sands in the Lysing and Lange Formations or at least to obtain stratigraphic information from these formations.
    Operations and results
    Wildcat well 6507/2-2 was spudded with the semi-submersible installation Polar Pioneer on 21 October 1991 and drilled to TD at 3958 m in Early Jurassic sediments of the Åre Formation. The well had 37% downtime due mainly to repeated occurrences of stuck drill pipe. Drilling went relatively smooth down to setting of the 9 5/8" casing shoe at 2760 m. After having cut two cores in the 8 1/2" section the well was shut in due to an influx at 3336 m. The well was killed with increased mud weight, but the pipe was found to be stuck. The pipe could not be freed and was cut at 3175 m. The well was then plugged back and sidetracked from 2989 m and drilled to 3326 m with minor problems. A 7" liner was run and set with shoe at 3324 m and the 6" section was then drilled to 3737 where parts of the bit sub was lost in the hole. This led to 20 days lost while attempting to recover the fish and sidetrack past the fish. Eventually the fish was partly recovered and drilling commenced to TD. The well was drilled with seawater and hi-vis pills down to 685 m and with a KCl/polymer mud from 685 m to TD.
    Oil shows were recorded on sandstone laminae in the interval 2208 ? 2750 m in the Shetland Group. The Cretaceous Lysing Formation was encountered at 2817.5 m, and the Lange Formation at 2831 m. A total of 23 m net sand was interpreted in the Cretaceous interval. Both Lysing and Lange Formation proved to be gas filled and the reservoirs were tested and exhibited fair to good production rates. Top Jurassic was encountered at 3380 m with a 292.5 m thick Melke Formation. Top Garn Formation came in at 3672.5 m. A total of 65.8 m net sand with an average porosity of 14.8% was penetrated in the Early and Middle Jurassic. The Jurassic sands were water filled, but weak to moderate shows were recorded on all cores from the Jurassic.
    Six cores were cut in the well. The two first were cut in the first hole from 2822 m to 2849.4 m in the Lysing and top Lange Formation and from 3278 m to 3296 m in the hydrocarbon-bearing Intra-Lange Formation sandstone. Cores 3 to 6 were cut in the sidetrack. Core 3 was cut over a second Intra-Lange sand from 3330 m to 3339.4 m; core 4 was cut from 3685 m to 3700 m in the Middle Jurassic Fangst Group, while core 5 and 6 were cut at 3770 m to 3778.5 m and at 3921 m to 3930 in sandstones of the Early Jurassic Båt Group. RFT fluid samples were taken at 3270.5 m (water and filtrate), 3280 m, 2825 m (water/filtrate and gas), and 3331.6 m (water/filtrate and gas).
    The well was permanently abandoned on 16 March 1992 as a gas condensate discovery.
    Testing
    Two DST tests were performed in the Cretaceous.
    DST 1A from the interval 3285.4 m to 3294.4 m in an intra- Lange Formation sandstone flowed 676000 Sm3 gas and 107 Sm3 oil/condensate per day through a 25.4mm choke. The GOR was 4950 Sm3/Sm3, the condensate density was 0.796 g/cm3, the gas gravity (air =1) was 0.63, and the gas contained 0.65 % CO2 and 0.2 ppm H2S. The bottom hole temperature recorded in the test was 118.4 deg C.
    DST 2 from 2820 m to 2831 m in the Lysing Formation flowed 865000 Sm3 gas and 80 Sm3 oil/condensate per day through a 25.5 mm choke. The GOR was 10800 Sm3/Sm3, the condensate density was 0.787 g/cm3, the gas gravity (air =1) was 0.645, and the gas contained 0.7 % CO2 and 0.1 ppm H2S. The bottom hole temperature recorded in the test was 99.1 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]
    690.00
    3957.00

  • 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
    2822.0
    2849.5
    [m ]
    2
    3273.0
    3295.8
    [m ]
    3
    3330.0
    3339.3
    [m ]
    4
    3685.4
    3700.4
    [m ]
    5
    3770.0
    3778.5
    [m ]
    6
    3921.0
    3929.3
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    91.4
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 2822-2827m
    Core photo at depth: 2827-2832m
    Core photo at depth: 2832-2837m
    Core photo at depth: 2837-2842m
    Core photo at depth: 2842-2847m
    2822-2827m
    2827-2832m
    2832-2837m
    2837-2842m
    2842-2847m
    Core photo at depth: 2847-2849m
    Core photo at depth: 3273-3278m
    Core photo at depth: 3278-3283m
    Core photo at depth: 3283-3288m
    Core photo at depth: 3288-3293m
    2847-2849m
    3273-3278m
    3278-3283m
    3283-3288m
    3288-3293m
    Core photo at depth: 3293-3295m
    Core photo at depth: 3330-3335m
    Core photo at depth: 3335-3339m
    Core photo at depth: 3685-3690m
    Core photo at depth: 3690-3695m
    3293-3295m
    3330-3335m
    3335-3339m
    3685-3690m
    3690-3695m
    Core photo at depth: 3695-3700m
    Core photo at depth: 3700-3701m
    Core photo at depth: 3770-3775m
    Core photo at depth: 3775-3778m
    Core photo at depth: 3921-3926m
    3695-3700m
    3700-3701m
    3770-3775m
    3775-3778m
    3921-3926m
    Core photo at depth: 3926-3929m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    3926-3929m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1456.0
    [m]
    SWC
    HYDRO
    1530.0
    [m]
    DC
    STRAT
    1560.0
    [m]
    DC
    STRAT
    1590.0
    [m]
    DC
    STRAT
    1600.0
    [m]
    SWC
    HYDRO
    1620.0
    [m]
    DC
    STRAT
    1650.0
    [m]
    DC
    STRAT
    1670.0
    [m]
    SWC
    HYDRO
    1680.0
    [m]
    DC
    STRAT
    1700.0
    [m]
    SWC
    HYDRO
    1710.0
    [m]
    DC
    STRAT
    1740.0
    [m]
    DC
    STRAT
    1760.0
    [m]
    SWC
    HYDRO
    1770.0
    [m]
    DC
    STRAT
    1780.0
    [m]
    DC
    STRAT
    1790.0
    [m]
    DC
    STRAT
    1800.0
    [m]
    DC
    STRAT
    1810.0
    [m]
    DC
    STRAT
    1820.0
    [m]
    DC
    STRAT
    1830.0
    [m]
    DC
    STRAT
    1851.0
    [m]
    SWC
    HYDRO
    1855.0
    [m]
    SWC
    HYDRO
    1860.0
    [m]
    DC
    STRAT
    1890.0
    [m]
    DC
    STRAT
    1899.0
    [m]
    SWC
    HYDRO
    1920.0
    [m]
    DC
    STRAT
    1930.0
    [m]
    SWC
    HYDRO
    1940.0
    [m]
    SWC
    HYDRO
    1980.0
    [m]
    DC
    STRAT
    1982.0
    [m]
    SWC
    HYDRO
    1992.0
    [m]
    SWC
    HYDRO
    2010.0
    [m]
    DC
    STRAT
    2040.0
    [m]
    DC
    STRAT
    2070.0
    [m]
    DC
    STRAT
    2070.0
    [m]
    SWC
    HYDRO
    2100.0
    [m]
    DC
    STRAT
    2130.0
    [m]
    DC
    STRAT
    2140.0
    [m]
    SWC
    HYDRO
    2160.0
    [m]
    DC
    STRAT
    2190.0
    [m]
    DC
    STRAT
    2208.0
    [m]
    SWC
    HYDRO
    2220.0
    [m]
    DC
    STRAT
    2235.0
    [m]
    DC
    STRAT
    2260.0
    [m]
    DC
    STRAT
    2280.0
    [m]
    SWC
    HYDRO
    2290.0
    [m]
    DC
    STRAT
    2320.0
    [m]
    DC
    STRAT
    2345.0
    [m]
    SWC
    HYDRO
    2350.0
    [m]
    DC
    STRAT
    2380.0
    [m]
    DC
    STRAT
    2424.0
    [m]
    SWC
    HYDRO
    2440.0
    [m]
    DC
    STRAT
    2470.0
    [m]
    DC
    STRAT
    2555.0
    [m]
    DC
    STRAT
    2615.0
    [m]
    DC
    STRAT
    2675.0
    [m]
    DC
    STRAT
    2700.0
    [m]
    SWC
    HYDRO
    2725.0
    [m]
    DC
    STRAT
    2750.0
    [m]
    DC
    STRAT
    2765.0
    [m]
    SWC
    HYDRO
    2775.0
    [m]
    DC
    STRAT
    2795.0
    [m]
    DC
    STRAT
    2800.0
    [m]
    DC
    STRAT
    2810.0
    [m]
    DC
    STRAT
    2818.0
    [m]
    SWC
    HYDRO
    2820.0
    [m]
    DC
    STRAT
    2822.2
    [m]
    C
    OD
    2822.6
    [m]
    C
    STRAT
    2822.7
    [m]
    DC
    STRAT
    2823.1
    [m]
    C
    OD
    2823.1
    [m]
    C
    STRAT
    2823.6
    [m]
    C
    STRAT
    2824.6
    [m]
    C
    STRAT
    2827.0
    [m]
    C
    STRAT
    2827.3
    [m]
    C
    STRAT
    2828.5
    [m]
    C
    STRAT
    2828.8
    [m]
    C
    OD
    2829.2
    [m]
    C
    STRAT
    2831.4
    [m]
    C
    STRAT
    2832.0
    [m]
    C
    STRAT
    2832.5
    [m]
    C
    STRAT
    2832.9
    [m]
    C
    STRAT
    2833.0
    [m]
    C
    STRAT
    2833.1
    [m]
    C
    STRAT
    2833.3
    [m]
    C
    OD
    2834.8
    [m]
    C
    STRAT
    2836.8
    [m]
    C
    OD
    2836.9
    [m]
    C
    STRAT
    2839.0
    [m]
    C
    STRAT
    2840.0
    [m]
    DC
    STRAT
    2840.4
    [m]
    C
    STRAT
    2841.8
    [m]
    C
    STRAT
    2844.0
    [m]
    C
    STRAT
    2845.1
    [m]
    C
    STRAT
    2849.0
    [m]
    C
    STRAT
    2849.4
    [m]
    C
    STRAT
    2860.0
    [m]
    DC
    STRAT
    2870.0
    [m]
    DC
    STRAT
    2880.0
    [m]
    DC
    STRAT
    2890.0
    [m]
    DC
    STRAT
    2900.0
    [m]
    DC
    STRAT
    2901.0
    [m]
    SWC
    HYDRO
    2910.0
    [m]
    DC
    STRAT
    2920.0
    [m]
    SWC
    HYDRO
    2930.0
    [m]
    DC
    STRAT
    2950.0
    [m]
    SWC
    HYDRO
    2960.0
    [m]
    DC
    STRAT
    2970.0
    [m]
    SWC
    HYDRO
    2980.0
    [m]
    DC
    STRAT
    3000.0
    [m]
    DC
    STRAT
    3020.0
    [m]
    DC
    STRAT
    3025.0
    [m]
    SWC
    HYDRO
    3030.0
    [m]
    DC
    STRAT
    3040.0
    [m]
    DC
    STRAT
    3050.0
    [m]
    DC
    STRAT
    3060.0
    [m]
    DC
    STRAT
    3070.0
    [m]
    DC
    STRAT
    3075.0
    [m]
    SWC
    HYDRO
    3080.0
    [m]
    DC
    STRAT
    3110.0
    [m]
    DC
    STRAT
    3122.0
    [m]
    SWC
    HYDRO
    3130.0
    [m]
    DC
    STRAT
    3140.0
    [m]
    DC
    STRAT
    3150.0
    [m]
    DC
    STRAT
    3160.0
    [m]
    DC
    STRAT
    3163.0
    [m]
    SWC
    HYDRO
    3170.0
    [m]
    DC
    STRAT
    3173.0
    [m]
    SWC
    HYDRO
    3180.0
    [m]
    DC
    STRAT
    3190.0
    [m]
    DC
    STRAT
    3194.0
    [m]
    SWC
    HYDRO
    3210.0
    [m]
    DC
    STRAT
    3225.0
    [m]
    DC
    STRAT
    3240.0
    [m]
    DC
    STRAT
    3251.0
    [m]
    SWC
    HYDR0
    3255.0
    [m]
    DC
    STRAT
    3260.0
    [m]
    DC
    STRAT
    3265.0
    [m]
    SWC
    HYDRO
    3270.0
    [m]
    SWC
    HYDRO
    3270.0
    [m]
    DC
    STRAT
    3273.0
    [m]
    DC
    STRAT
    3274.0
    [m]
    C
    STRAT
    3275.0
    [m]
    SWC
    HYDRO
    3275.0
    [m]
    C
    STRAT
    3277.0
    [m]
    C
    STRAT
    3279.0
    [m]
    C
    STRAT
    3286.9
    [m]
    C
    STRAT
    3287.0
    [m]
    C
    STRAT
    3288.0
    [m]
    C
    HYDRO
    3294.3
    [m]
    C
    STRAT
    3294.7
    [m]
    C
    STRAT
    3295.0
    [m]
    SWC
    HYDRO
    3295.0
    [m]
    SWC
    HYDRO
    3300.0
    [m]
    DC
    STRAT
    3305.0
    [m]
    DC
    STRAT
    3307.0
    [m]
    DC
    STRAT
    3310.0
    [m]
    DC
    STRAT
    3320.0
    [m]
    DC
    STRAT
    3325.0
    [m]
    SWC
    HYDRO
    3326.0
    [m]
    DC
    STRAT
    3327.0
    [m]
    DC
    STRAT
    3329.9
    [m]
    SWC
    HYDRO
    3330.1
    [m]
    C
    STRAT
    3335.0
    [m]
    C
    STRAT
    3335.0
    [m]
    DC
    STRAT
    3338.6
    [m]
    C
    STRAT
    3345.0
    [m]
    DC
    STRAT
    3350.0
    [m]
    DC
    STRAT
    3355.0
    [m]
    DC
    STRAT
    3360.0
    [m]
    DC
    STRAT
    3365.0
    [m]
    DC
    STRAT
    3367.3
    [m]
    SWC
    HYDRO
    3370.0
    [m]
    DC
    STRAT
    3373.0
    [m]
    SWC
    HYDRO
    3375.0
    [m]
    DC
    STRAT
    3380.0
    [m]
    DC
    STRAT
    3383.2
    [m]
    SWC
    HYDRO
    3385.0
    [m]
    DC
    STRAT
    3395.0
    [m]
    DC
    STRAT
    3400.0
    [m]
    DC
    STRAT
    3405.0
    [m]
    DC
    STRAT
    3410.0
    [m]
    DC
    STRAT
    3415.0
    [m]
    DC
    STRAT
    3420.0
    [m]
    DC
    STRAT
    3425.0
    [m]
    DC
    STRAT
    3430.0
    [m]
    DC
    STRAT
    3435.0
    [m]
    DC
    STRAT
    3440.0
    [m]
    DC
    STRAT
    3445.0
    [m]
    DC
    STRAT
    3450.0
    [m]
    DC
    STRAT
    3455.0
    [m]
    DC
    STRAT
    3460.0
    [m]
    DC
    STRAT
    3465.0
    [m]
    DC
    STRAT
    3470.0
    [m]
    DC
    STRAT
    3475.0
    [m]
    DC
    STRAT
    3480.0
    [m]
    DC
    STRAT
    3485.0
    [m]
    DC
    STRAT
    3490.0
    [m]
    DC
    STRAT
    3495.0
    [m]
    DC
    STRAT
    3500.0
    [m]
    DC
    STRAT
    3508.4
    [m]
    SWC
    HYDRO
    3510.0
    [m]
    DC
    STRAT
    3517.0
    [m]
    DC
    STRAT
    3530.0
    [m]
    DC
    STRAT
    3540.0
    [m]
    DC
    STRAT
    3545.0
    [m]
    DC
    STRAT
    3550.0
    [m]
    DC
    STRAT
    3555.0
    [m]
    DC
    STRAT
    3560.0
    [m]
    DC
    STRAT
    3570.0
    [m]
    DC
    STRAT
    3580.0
    [m]
    DC
    STRAT
    3590.0
    [m]
    DC
    STRAT
    3600.0
    [m]
    DC
    STRAT
    3610.0
    [m]
    DC
    STRAT
    3612.2
    [m]
    SWC
    HYDRO
    3620.0
    [m]
    DC
    STRAT
    3630.0
    [m]
    DC
    STRAT
    3640.0
    [m]
    DC
    STRAT
    3650.0
    [m]
    DC
    STRAT
    3660.0
    [m]
    DC
    STRAT
    3665.0
    [m]
    DC
    STRAT
    3670.0
    [m]
    DC
    STRAT
    3680.0
    [m]
    DC
    STRAT
    3685.0
    [m]
    DC
    STRAT
    3685.7
    [m]
    C
    STRAT
    3700.0
    [m]
    DC
    STRAT
    3700.4
    [m]
    C
    STRAT
    3705.0
    [m]
    DC
    STRAT
    3710.0
    [m]
    DC
    STRAT
    3715.0
    [m]
    DC
    STRAT
    3720.0
    [m]
    DC
    STRAT
    3725.0
    [m]
    DC
    STRAT
    3730.0
    [m]
    DC
    STRAT
    3735.0
    [m]
    DC
    STRAT
    3737.0
    [m]
    DC
    STRAT
    3740.0
    [m]
    DC
    STRAT
    3743.2
    [m]
    SWC
    HYDRO
    3745.0
    [m]
    DC
    STRAT
    3750.0
    [m]
    DC
    STRAT
    3760.0
    [m]
    DC
    STRAT
    3770.0
    [m]
    DC
    STRAT
    3772.8
    [m]
    C
    STRAT
    3774.8
    [m]
    C
    STRAT
    3778.4
    [m]
    C
    STRAT
    3780.0
    [m]
    DC
    STRAT
    3784.0
    [m]
    SWC
    HYDRO
    3784.0
    [m]
    SWC
    HYDRO
    3785.0
    [m]
    DC
    STRAT
    3790.0
    [m]
    DC
    STRAT
    3795.0
    [m]
    DC
    STRAT
    3800.0
    [m]
    DC
    STRAT
    3810.0
    [m]
    DC
    STRAT
    3820.0
    [m]
    DC
    STRAT
    3830.0
    [m]
    DC
    STRAT
    3842.0
    [m]
    DC
    STRAT
    3851.0
    [m]
    SWC
    HYDRO
    3852.0
    [m]
    DC
    STRAT
    3862.0
    [m]
    DC
    STRAT
    3872.0
    [m]
    DC
    STRAT
    3882.0
    [m]
    DC
    STRAT
    3892.0
    [m]
    DC
    STRAT
    3902.0
    [m]
    DC
    STRAT
    3912.0
    [m]
    DC
    STRAT
    3920.0
    [m]
    DC
    STRAT
    3922.0
    [m]
    C
    STRAT
    3923.6
    [m]
    C
    STRAT
    3925.0
    [m]
    C
    STRAT
    3928.5
    [m]
    C
    STRAT
    3929.0
    [m]
    C
    STRAT
    3929.4
    [m]
    C
    STRAT
    3932.0
    [m]
    DC
    STRAT
    3940.0
    [m]
    DC
    STRAT
    3950.0
    [m]
    DC
    STRAT
    3957.0
    [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
    TEST1A
    3294.00
    3285.00
    CONDENSATE
    16.02.1992 - 23:00
    YES
    DST
    TEST2
    2831.00
    2820.00
    02.03.1992 - 03:57
    YES

  • Lithostratigraphy

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.51
    pdf
    1.50
    pdf
    0.67
    pdf
    0.33
    pdf
    2.28
    pdf
    1.35

  • 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
    20.03

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    3285
    3294
    25.4
    2.0
    2820
    2831
    25.4
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    2.0
    Drill stem tests (DST)
    Test number
    Oil
    [Sm3/day]
    Gas
    [Sm3/day]
    Oil density
    [g/cm3]
    Gas grav. rel.air
    GOR
    [m3/m3]
    1.0
    107
    676000
    0.790
    0.630
    6317
    2.0
    80
    865000
    0.780
    0.640
    1081

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL VDL GR CCC
    1900
    2597
    CST
    1940
    2097
    CST
    2115
    2591
    CST
    2610
    3249
    DLL MSFL GR SP
    2100
    2602
    ISF BHC MSFL GR SP
    474
    3250
    LDT CNL GR
    1026
    3250
    MWD
    474
    3262
    RFT
    2205
    2574
    SHDT GR
    1026
    3250
    TEMP
    500
    2025
    TEMP
    998
    2551
    VSP
    474
    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
    491.0
    36
    491.0
    0.00
    LOT
    INTERM.
    18 5/8
    671.0
    24
    685.0
    1.48
    LOT
    INTERM.
    13 3/8
    1399.0
    17 1/2
    1414.0
    1.72
    LOT
    INTERM.
    9 5/8
    2761.0
    12 1/4
    2777.0
    2.02
    LOT
    INTERM.
    7
    3324.0
    8 1/2
    3958.0
    2.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    407
    1.00
    WATER BASED
    430
    1.61
    16.0
    WATER BASED
    491
    1.05
    18.0
    WATER BASED
    505
    1.05
    18.0
    WATER BASED
    685
    1.05
    18.0
    WATER BASED
    1051
    1.26
    17.0
    WATER BASED
    1238
    1.60
    12.0
    WATER BASED
    1259
    1.26
    13.0
    WATER BASED
    1414
    1.26
    14.0
    WATER BASED
    1600
    1.30
    14.0
    WATER BASED
    1959
    1.51
    20.0
    WATER BASED
    2100
    1.55
    18.0
    WATER BASED
    2355
    1.55
    25.0
    WATER BASED
    2449
    1.55
    24.0
    WATER BASED
    2517
    1.57
    25.0
    WATER BASED
    2568
    1.70
    13.0
    WATER BASED
    2568
    1.70
    15.0
    WATER BASED
    2727
    1.57
    23.0
    WATER BASED
    2775
    1.60
    28.0
    WATER BASED
    2777
    1.60
    28.0
    WATER BASED
    2783
    1.50
    22.0
    WATER BASED
    2821
    1.50
    19.0
    WATER BASED
    2843
    1.50
    20.0
    WATER BASED
    2863
    1.50
    20.0
    WATER BASED
    2900
    1.70
    22.0
    WATER BASED
    2924
    1.50
    19.0
    WATER BASED
    2987
    1.50
    19.0
    WATER BASED
    2989
    1.70
    23.0
    WATER BASED
    3013
    1.50
    17.0
    WATER BASED
    3045
    1.50
    17.0
    WATER BASED
    3084
    1.70
    25.0
    WATER BASED
    3112
    1.70
    26.0
    WATER BASED
    3154
    1.70
    24.0
    WATER BASED
    3156
    1.50
    15.0
    WATER BASED
    3161
    1.70
    24.0
    WATER BASED
    3175
    1.70
    22.0
    WATER BASED
    3188
    1.70
    25.0
    WATER BASED
    3212
    1.86
    26.0
    WATER BASED
    3257
    1.70
    28.0
    WATER BASED
    3265
    1.50
    16.0
    WATER BASED
    3274
    1.86
    27.0
    WATER BASED
    3283
    1.62
    13.0
    WATER BASED
    3296
    1.50
    16.0
    WATER BASED
    3307
    1.86
    27.0
    WATER BASED
    3326
    1.70
    24.0
    WATER BASED
    3330
    1.75
    20.0
    WATER BASED
    3336
    1.70
    25.0
    WATER BASED
    3448
    1.75
    20.0
    WATER BASED
    3570
    1.75
    23.0
    WATER BASED
    3626
    1.86
    31.0
    WATER BASED
    3638
    1.75
    24.0
    WATER BASED
    3670
    1.86
    28.0
    WATER BASED
    3678
    1.75
    23.0
    WATER BASED
    3684
    1.86
    30.0
    WATER BASED
    3685
    1.86
    27.0
    WATER BASED
    3696
    1.86
    27.0
    WATER BASED
    3700
    1.86
    28.0
    WATER BASED
    3702
    1.86
    29.0
    WATER BASED
    3705
    1.86
    31.0
    WATER BASED
    3710
    1.86
    31.0
    WATER BASED
    3712
    1.86
    29.0
    WATER BASED
    3721
    1.86
    30.0
    WATER BASED
    3736
    1.86
    31.0
    WATER BASED
    3737
    1.86
    27.0
    WATER BASED
    3739
    1.86
    32.0
    WATER BASED
    3741
    1.86
    30.0
    WATER BASED
    3751
    1.86
    30.0
    WATER BASED
    3770
    1.86
    31.0
    WATER BASED
    3796
    1.86
    31.0
    WATER BASED
    3910
    1.86
    31.0
    WATER BASED
    3958
    1.86
    28.0
    WATER BASED
    3958
    1.86
    33.0
    WATER BASED

  • Thin sections at the Norwegian Offshore Directorate
    Thin sections at the Norwegian Offshore Directorate
    Depth
    Unit
    2824.25
    [m ]
    2825.00
    [m ]
    2826.25
    [m ]
    2828.05
    [m ]
    2831.25
    [m ]
    3281.00
    [m ]
    3282.50
    [m ]
    3284.00
    [m ]
    3286.50
    [m ]
    3287.75
    [m ]
    3291.75
    [m ]
    3335.50
    [m ]
    3337.25
    [m ]
    3337.50
    [m ]
    3687.50
    [m ]
    3690.00
    [m ]
    3691.65
    [m ]
    3692.45
    [m ]
    3694.22
    [m ]
    3695.50
    [m ]
    3698.50
    [m ]
    3698.75
    [m ]
    3771.25
    [m ]
    3777.00
    [m ]
    3275.25
    [m ]
    3281.01
    [m ]
    3285.50
    [m ]
    3286.75
    [m ]
    3293.00
    [m ]
    3295.00
    [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
    0.28