Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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22.11.2024 - 09:09
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35/3-4

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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.
    35/3-4
    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
    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.
    35/3-4
    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.
    Saga Petroleum ASA
    Drill permit
    The drilling permit number together with the version of the drilling permit as stated in the drilling permit granted by the Norwegian Offshore Directorate.
    272-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.
    189
    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,
    30.11.1980
    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.
    06.06.1981
    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.
    06.06.1983
    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.
    18.05.2004
    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.
    EARLY 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.
    AGAT FM
    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.
    258.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4089.0
    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).
    4087.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    3.5
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    125
    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.
    PRE-DEVONIAN
    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.
    BASEMENT
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    61° 51' 54.54'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    3° 52' 26.99'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6859631.80
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    545989.90
    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.
    219

  • Wellbore history
    General
    Wildcat wells 35/3-3 and 35/3-4 were drilled in the Norwegian sector of the North Sea approximately 50 km west of MålØy, Norway. The primary target was to test the possible extension of Lower Cretaceous sandstones to the east of those encountered in wells 35/3-1 and 35/3-2. A stratigraphic trap was thought to exist in these sandstones. A secondary target was possible sandstones of Early Jurassic age with a possible pinch-out trap.
    Well 35/3-3 was spudded with the semi-submersible installation Byford Dolphin on 30 October 1980. It was drilled and logged to 900 m, then junked because of technical problems running the 20" casing. The rig was moved about 20 meters, and the well was respudded as 35/3-4.
    Operations and results
    Well 35/3-4 was spudded with the semi-submersible installation Byford Dolphin on 30 November 1980 and drilled to TD at 4089 m in Basement rocks (Caledonian age). A sidetrack was drilled from 3768 m. The well was drilled with seawater and gel down to 457m, with seawater/gel/lignosulfonate from 457 m to 879 m, with lignosulfonate/gypsum/gel mud from 879 m to 2388 m, and with gel/lignosulfonate/PAC mud from 2388 m to TD.
    The well penetrated strata from Tertiary through Jurassic before reaching basement rocks-of Caledonian age.
    Hydrocarbon shows were encountered in Lower Cretaceous and Lower-Middle Jurassic sand. The Lower Cretaceous sediments were interpreted as submarine fans. RFT measurements in Lower Cretaceous indicate an upper zone with a gas gradient of 0.4 psi/m, and a deeper zone with a water gradient of 1,54 psi/m. There seem to be no pressure communication between these two zones. Log evaluation indicate 13 m net thickness in the interval 3445 m to 3471 m, with an average porosity of 19 % and an average water saturation of 52 %.
    Organic geochemical analyses showed poor, immature to marginally mature source rocks with limited potential for gas/condensate down to ca 3200 m. At 3200 m to ca 3650 metres zones of medium to dark grey shales have useful TOC (up to ca 3%) but are effectively immature in well position and have a negligible potential for gas (hydrogen index from 50 to 150 mg HC/g TOC).
    Abundant medium to dark grey and dark olive grey shales occur in zones from 3650 m to TD.  Although they are generally poor source rocks scattered fair and good to very good interbeds are also present, notably in the Heather Formation and below 4000 m (base of Cook). The best interval was found in the interval 3695 m to 3725 m in the Heather Formation (TOC from 3.1 % to 3.8 % and hydrogen index from 260 mg/g to 360 mg/g). Their marginal maturity will, however, limit hydrocarbon generation on-structure to minor volumes of gas and associated liquids. Ten cores were cut in the Agat Formation from 3400.6 m to 3543 m and one core was cut in basement at TD from 4087 m to 4088.8 m.
    The well was plugged and abandoned on 6 June 1981 as a gas/condensate appraisal of the 35/3-2 Agat Discovery.
    Testing
    Three drill stem tests were performed in the Lower Cretaceous sequence. In DST1 the intervals 3488.50 m to 3495.00, 3498.25 m to 3503.25, and 3504.50 m to 3507.75 were perforated, but no fluids were produced.  In DST2 the intervals 3445.00 m to 3447.5, 3449.25 m to 3453.5, 3454.5 m to 3459.5, and 3464.0 m to 3471.5 were perforated, but due to technical problems the test was abandoned. The final test, named DST 2A the same perforation intervals as in DST2 were used. Final gas flow rate under the first main flow period was 688000 Sm3/day and the corresponding condensate flow rate was 84 Sm3/day on a 36/64" choke. This correspond to a GOR of  8200 Sm3/Sm3. The gas gravity was 0.62 (air = 1) and condensate gravity was 50.3 °API.
    Based on the test results from both 35/3-2 and 35/3-4 the reservoir encountered in 35/3-2 was interpreted as close to its dew point, while the 35/3-4 reservoir may not be. The reservoir penetrated by 35/3-4 is in a different pressure regime showing the two reservoirs to be different.

  • 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]
    890.00
    4086.00

  • 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
    3400.6
    3415.4
    [m ]
    2
    3447.3
    3457.6
    [m ]
    3
    3458.5
    3459.6
    [m ]
    4
    3459.7
    3478.1
    [m ]
    5
    3478.1
    3488.6
    [m ]
    6
    3491.8
    3497.0
    [m ]
    7
    3497.8
    3509.5
    [m ]
    8
    3509.5
    3514.8
    [m ]
    9
    3518.0
    3530.7
    [m ]
    10
    3536.0
    3542.8
    [m ]
    11
    4087.0
    4088.5
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    98.2
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 3400-3403m
    Core photo at depth: 3403-3406m
    Core photo at depth: 3406-3408m
    Core photo at depth: 3408-3411m
    Core photo at depth: 3411-3414m
    3400-3403m
    3403-3406m
    3406-3408m
    3408-3411m
    3411-3414m
    Core photo at depth: 3414-3415m
    Core photo at depth: 3447-3450m
    Core photo at depth: 3450-3452m
    Core photo at depth: 3452-3455m
    Core photo at depth: 3455-3457m
    3414-3415m
    3447-3450m
    3450-3452m
    3452-3455m
    3455-3457m
    Core photo at depth: 3458-3459m
    Core photo at depth: 3459-3462m
    Core photo at depth: 3462-3465m
    Core photo at depth: 3465-3467m
    Core photo at depth: 3467-3470m
    3458-3459m
    3459-3462m
    3462-3465m
    3465-3467m
    3467-3470m
    Core photo at depth: 3470-3473m
    Core photo at depth: 3473-3475m
    Core photo at depth: 3475-3481m
    Core photo at depth: 3478-3480m
    Core photo at depth: 3480-3483m
    3470-3473m
    3473-3475m
    3475-3481m
    3478-3480m
    3480-3483m
    Core photo at depth: 3483-3486m
    Core photo at depth: 3486-3488m
    Core photo at depth: 3497-3500m
    Core photo at depth: 3500-3503m
    Core photo at depth: 3491-3494m
    3483-3486m
    3486-3488m
    3497-3500m
    3500-3503m
    3491-3494m
    Core photo at depth: 3494-3497m
    Core photo at depth: 3503-3505m
    Core photo at depth: 3505-3508m
    Core photo at depth: 3503-3505m
    Core photo at depth: 3505-3508m
    3494-3497m
    3503-3505m
    3505-3508m
    3503-3505m
    3505-3508m
    Core photo at depth: 3508-3509m
    Core photo at depth: 4087-4088m
    Core photo at depth: 3509-3512m
    Core photo at depth: 3512-3514m
    Core photo at depth: 3518-3520m
    3508-3509m
    4087-4088m
    3509-3512m
    3512-3514m
    3518-3520m
    Core photo at depth: 3520-3523m
    Core photo at depth: 3523-3526m
    Core photo at depth: 3526-3528m
    Core photo at depth: 3528-3530m
    Core photo at depth: 3536-3538m
    3520-3523m
    3523-3526m
    3526-3528m
    3528-3530m
    3536-3538m
    Core photo at depth: 3538-3541m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    3538-3541m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    660.0
    [m]
    DC
    RRI
    1020.0
    [m]
    DC
    ROBERTSO
    1030.0
    [m]
    DC
    ROBERTSO
    1040.0
    [m]
    DC
    ROBERTSO
    1070.0
    [m]
    DC
    ROBERTSO
    1080.0
    [m]
    DC
    ROBERTSO
    1090.0
    [m]
    DC
    ROBERTSO
    1100.0
    [m]
    DC
    ROBERTSO
    1110.0
    [m]
    DC
    ROBERTSO
    1120.0
    [m]
    DC
    ROBERTSO
    1130.0
    [m]
    DC
    ROBERTSO
    1140.0
    [m]
    DC
    ROBERTSO
    1150.0
    [m]
    DC
    ROBERTSO
    1160.0
    [m]
    DC
    ROBERTSO
    1170.0
    [m]
    DC
    ROBERTSO
    1180.0
    [m]
    DC
    ROBERTSO
    1190.0
    [m]
    DC
    ROBERTSO
    1200.0
    [m]
    DC
    ROBERTSO
    1210.0
    [m]
    DC
    ROBERTSO
    1210.0
    [m]
    DC
    RRI
    1220.0
    [m]
    DC
    ROBERTSO
    1230.0
    [m]
    DC
    ROBERTSO
    1240.0
    [m]
    DC
    ROBERTSO
    1250.0
    [m]
    DC
    ROBERTSO
    1260.0
    [m]
    DC
    ROBERTSO
    1270.0
    [m]
    DC
    ROBERTSO
    1280.0
    [m]
    DC
    ROBERTSO
    1290.0
    [m]
    DC
    ROBERTSO
    1300.0
    [m]
    DC
    ROBERTSO
    1310.0
    [m]
    DC
    R
    1320.0
    [m]
    DC
    ROBERTSO
    1330.0
    [m]
    DC
    ROBERTSO
    1340.0
    [m]
    DC
    ROBERTSO
    1350.0
    [m]
    DC
    ROBERTSO
    1360.0
    [m]
    DC
    ROBERTSO
    1370.0
    [m]
    DC
    ROBERTSO
    1380.0
    [m]
    DC
    ROBERTSO
    1390.0
    [m]
    DC
    ROBERTSO
    1400.0
    [m]
    DC
    ROBERTSO
    1410.0
    [m]
    DC
    RRI
    1420.0
    [m]
    DC
    ROBERTSO
    1440.0
    [m]
    DC
    ROBERTSO
    1450.0
    [m]
    DC
    ROBERTSO
    1460.0
    [m]
    DC
    ROBERTSO
    1470.0
    [m]
    DC
    RRI
    1490.0
    [m]
    DC
    RRI
    1510.0
    [m]
    DC
    RRI
    1530.0
    [m]
    DC
    RRI
    1550.0
    [m]
    DC
    RRI
    1570.0
    [m]
    DC
    RRI
    1590.0
    [m]
    DC
    RRI
    1610.0
    [m]
    DC
    RRI
    1630.0
    [m]
    DC
    RRI
    1650.0
    [m]
    DC
    RRI
    1670.0
    [m]
    DC
    RRI
    1690.0
    [m]
    DC
    RRI
    1710.0
    [m]
    DC
    RRI
    1730.0
    [m]
    DC
    RRI
    1750.0
    [m]
    DC
    RRI
    1770.0
    [m]
    DC
    RRI
    1790.0
    [m]
    DC
    RRI
    1810.0
    [m]
    DC
    RRI
    1830.0
    [m]
    DC
    RRI
    1850.0
    [m]
    DC
    RRI
    1870.0
    [m]
    DC
    RRI
    1890.0
    [m]
    DC
    RRI
    1910.0
    [m]
    DC
    RRI
    1930.0
    [m]
    DC
    RRI
    1990.0
    [m]
    DC
    RRI
    2010.0
    [m]
    DC
    RRI
    2030.0
    [m]
    DC
    RRI
    2050.0
    [m]
    DC
    RRI
    2070.0
    [m]
    DC
    RRI
    2090.0
    [m]
    DC
    RRI
    2110.0
    [m]
    DC
    RRI
    2120.0
    [m]
    DC
    RRI
    2130.0
    [m]
    DC
    RRI
    2150.0
    [m]
    DC
    RRI
    2170.0
    [m]
    DC
    RRI
    2190.0
    [m]
    DC
    RRI
    2210.0
    [m]
    DC
    RRI
    2230.0
    [m]
    DC
    RRI
    2250.0
    [m]
    DC
    RRI
    2270.0
    [m]
    DC
    RRI
    2290.0
    [m]
    DC
    RRI
    2310.0
    [m]
    DC
    RRI
    2330.0
    [m]
    DC
    RRI
    2350.0
    [m]
    DC
    RRI
    2370.0
    [m]
    DC
    RRI
    2385.0
    [m]
    DC
    RRI
    2405.0
    [m]
    DC
    RRI
    2425.0
    [m]
    DC
    RRI
    2445.0
    [m]
    DC
    RRI
    2465.0
    [m]
    DC
    RRI
    2485.0
    [m]
    DC
    RRI
    2505.0
    [m]
    DC
    RRI
    2525.0
    [m]
    DC
    RRI
    2545.0
    [m]
    DC
    RRI
    2565.0
    [m]
    DC
    RRI
    2585.0
    [m]
    DC
    RRI
    2605.0
    [m]
    DC
    RRI
    2625.0
    [m]
    DC
    RRI
    2645.0
    [m]
    DC
    RRI
    2665.0
    [m]
    DC
    RRI
    2680.0
    [m]
    DC
    RRI
    2700.0
    [m]
    DC
    RRI
    2720.0
    [m]
    DC
    RRI
    2740.0
    [m]
    DC
    RRI
    2760.0
    [m]
    DC
    RRI
    2780.0
    [m]
    DC
    RRI
    2800.0
    [m]
    DC
    RRI
    2805.0
    [m]
    DC
    RRI
    2820.0
    [m]
    DC
    RRI
    2840.0
    [m]
    DC
    RRI
    2860.0
    [m]
    DC
    RRI
    2880.0
    [m]
    DC
    RRI
    3000.0
    [m]
    DC
    RRI
    3020.0
    [m]
    DC
    RRI
    3040.0
    [m]
    DC
    RRI
    3090.0
    [m]
    DC
    RRI
    3110.0
    [m]
    DC
    RRI
    3130.0
    [m]
    DC
    RRI
    3200.0
    [m]
    DC
    RRI
    3221.0
    [m]
    DC
    RRI
    3236.0
    [m]
    DC
    RRI
    3251.0
    [m]
    DC
    RRI
    3266.0
    [m]
    DC
    RRI
    3281.0
    [m]
    DC
    RRI
    3296.0
    [m]
    DC
    RRI
    3311.0
    [m]
    DC
    RRI
    3323.0
    [m]
    DC
    RRI
    3326.0
    [m]
    DC
    RRI
    3338.0
    [m]
    DC
    RRI
    3353.0
    [m]
    DC
    OD
    3359.0
    [m]
    DC
    RRI
    3362.0
    [m]
    DC
    RRI
    3374.0
    [m]
    DC
    RRI
    3389.0
    [m]
    DC
    RRI
    3400.6
    [m]
    C
    RRI
    3400.8
    [m]
    C
    OD
    3401.2
    [m]
    DC
    OD
    3401.8
    [m]
    C
    OD
    3402.8
    [m]
    C
    OD
    3403.6
    [m]
    C
    OD
    3404.0
    [m]
    DC
    RRI
    3404.4
    [m]
    C
    OD
    3404.5
    [m]
    C
    RRI
    3404.8
    [m]
    C
    OD
    3405.0
    [m]
    DC
    OD
    3405.9
    [m]
    C
    OD
    3405.9
    [m]
    C
    OD
    3406.6
    [m]
    C
    OD
    3406.6
    [m]
    C
    OD
    3407.0
    [m]
    DC
    OD
    3407.2
    [m]
    C
    OD
    3408.3
    [m]
    C
    OD
    3409.0
    [m]
    C
    RRI
    3409.3
    [m]
    C
    OD
    3410.0
    [m]
    C
    OD
    3410.0
    [m]
    C
    OD
    3410.7
    [m]
    C
    OD
    3410.8
    [m]
    C
    OD
    3412.0
    [m]
    C
    OD
    3412.1
    [m]
    DC
    OD
    3412.5
    [m]
    C
    RRI
    3412.9
    [m]
    C
    OD
    3413.5
    [m]
    DC
    OD
    3414.0
    [m]
    C
    OD
    3415.3
    [m]
    C
    RRI
    3415.4
    [m]
    C
    OD
    3422.0
    [m]
    DC
    RRI
    3427.0
    [m]
    DC
    OD
    3437.0
    [m]
    DC
    RRI
    3439.0
    [m]
    DC
    OD
    3447.0
    [m]
    DC
    OD
    3447.3
    [m]
    C
    OD
    3448.2
    [m]
    C
    STATOIL
    3448.6
    [m]
    C
    OD
    3449.8
    [m]
    C
    OD
    3450.0
    [m]
    C
    STATOIL
    3450.2
    [m]
    DC
    OD
    3450.5
    [m]
    C
    RRI
    3450.8
    [m]
    C
    OD
    3450.8
    [m]
    C
    OD
    3450.8
    [m]
    C
    OD
    3451.8
    [m]
    C
    OD
    3452.0
    [m]
    DC
    RRI
    3452.8
    [m]
    C
    OD
    3454.8
    [m]
    C
    OD
    3456.0
    [m]
    C
    OD
    3456.0
    [m]
    C
    OD
    3456.2
    [m]
    C
    RRI
    3456.6
    [m]
    C
    OD
    3456.7
    [m]
    C
    OD
    3457.0
    [m]
    C
    OD
    3457.4
    [m]
    C
    OD
    3457.4
    [m]
    C
    OD
    3458.9
    [m]
    C
    OD
    3459.0
    [m]
    C
    OD
    3459.5
    [m]
    C
    RRI
    3459.6
    [m]
    C
    OD
    3459.6
    [m]
    C
    OD
    3459.9
    [m]
    C
    OD
    3461.0
    [m]
    C
    OD
    3462.3
    [m]
    C
    OD
    3463.2
    [m]
    C
    OD
    3464.2
    [m]
    C
    OD
    3464.8
    [m]
    C
    OD
    3464.9
    [m]
    C
    OD
    3465.0
    [m]
    C
    OD
    3465.0
    [m]
    C
    RRI
    3465.0
    [m]
    C
    STATOIL
    3466.5
    [m]
    C
    OD
    3467.0
    [m]
    DC
    RRI
    3467.7
    [m]
    C
    OD
    3469.0
    [m]
    C
    OD
    3469.3
    [m]
    C
    OD
    3469.3
    [m]
    C
    OD
    3469.7
    [m]
    C
    OD
    3470.5
    [m]
    C
    OD
    3471.0
    [m]
    C
    OD
    3471.2
    [m]
    C
    OD
    3471.2
    [m]
    C
    OD
    3471.2
    [m]
    C
    OD
    3471.6
    [m]
    C
    RRI
    3472.3
    [m]
    C
    OD
    3473.0
    [m]
    C
    OD
    3474.0
    [m]
    C
    OD
    3474.1
    [m]
    C
    OD
    3474.7
    [m]
    C
    OD
    3474.8
    [m]
    C
    RRI
    3474.9
    [m]
    C
    RRI
    3475.0
    [m]
    C
    OD
    3475.7
    [m]
    C
    OD
    3475.8
    [m]
    C
    OD
    3477.2
    [m]
    C
    OD
    3477.3
    [m]
    C
    OD
    3477.4
    [m]
    C
    OD
    3478.1
    [m]
    C
    OD
    3479.7
    [m]
    C
    OD
    3479.8
    [m]
    C
    OD
    3480.2
    [m]
    C
    OD
    3481.1
    [m]
    C
    OD
    3481.1
    [m]
    C
    OD
    3482.0
    [m]
    DC
    STATOIL
    3482.2
    [m]
    C
    OD
    3483.1
    [m]
    C
    OD
    3483.2
    [m]
    C
    OD
    3483.2
    [m]
    C
    RRI
    3483.5
    [m]
    C
    OD
    3483.5
    [m]
    C
    RRI
    3483.7
    [m]
    C
    OD
    3483.8
    [m]
    C
    OD
    3485.8
    [m]
    C
    OD
    3486.2
    [m]
    C
    STATOIL
    3486.8
    [m]
    C
    OD
    3487.7
    [m]
    C
    OD
    3487.8
    [m]
    C
    OD
    3488.6
    [m]
    C
    OD
    3491.9
    [m]
    C
    OD
    3492.0
    [m]
    C
    RRI
    3492.4
    [m]
    C
    OD
    3493.3
    [m]
    C
    OD
    3493.5
    [m]
    C
    OD
    3494.5
    [m]
    C
    OD
    3494.9
    [m]
    C
    OD
    3495.2
    [m]
    C
    OD
    3495.3
    [m]
    C
    OD
    3495.4
    [m]
    C
    STATOIL
    3497.9
    [m]
    C
    OD
    3500.0
    [m]
    DC
    STATOIL
    3505.2
    [m]
    C
    OD
    3505.2
    [m]
    C
    OD
    3505.3
    [m]
    C
    OD
    3505.4
    [m]
    C
    RRI
    3506.2
    [m]
    C
    OD
    3506.3
    [m]
    C
    OD
    3507.1
    [m]
    C
    OD
    3507.2
    [m]
    C
    OD
    3507.2
    [m]
    C
    OD
    3508.0
    [m]
    C
    OD
    3508.1
    [m]
    C
    OD
    3509.1
    [m]
    C
    OD
    3509.5
    [m]
    C
    RRI
    3510.3
    [m]
    C
    OD
    3510.4
    [m]
    C
    OD
    3510.9
    [m]
    C
    OD
    3511.1
    [m]
    C
    OD
    3511.1
    [m]
    C
    OD
    3511.7
    [m]
    C
    OD
    3511.7
    [m]
    C
    OD
    3512.3
    [m]
    C
    RRI
    3512.4
    [m]
    C
    OD
    3512.7
    [m]
    C
    OD
    3513.7
    [m]
    C
    OD
    3514.0
    [m]
    C
    OD
    3514.6
    [m]
    C
    RRI
    3514.7
    [m]
    C
    OD
    3514.8
    [m]
    C
    OD
    3515.0
    [m]
    DC
    STATOIL
    3518.7
    [m]
    C
    OD
    3518.8
    [m]
    C
    OD
    3518.8
    [m]
    C
    RRI
    3519.7
    [m]
    C
    OD
    3519.8
    [m]
    C
    OD
    3520.7
    [m]
    C
    OD
    3521.0
    [m]
    C
    OD
    3521.1
    [m]
    C
    OD
    3522.1
    [m]
    C
    OD
    3522.3
    [m]
    C
    OD
    3523.6
    [m]
    C
    OD
    3523.8
    [m]
    C
    OD
    3523.9
    [m]
    C
    OD
    3524.9
    [m]
    C
    OD
    3525.0
    [m]
    C
    OD
    3526.0
    [m]
    C
    OD
    3527.4
    [m]
    C
    OD
    3527.9
    [m]
    C
    STATOIL
    3528.7
    [m]
    C
    OD
    3529.7
    [m]
    C
    OD
    3530.6
    [m]
    C
    OD
    3533.0
    [m]
    DC
    STATOIL
    3536.2
    [m]
    C
    OD
    3537.3
    [m]
    C
    OD
    3538.6
    [m]
    C
    OD
    3539.8
    [m]
    C
    OD
    3539.9
    [m]
    C
    OD
    3539.9
    [m]
    C
    RRI
    3541.0
    [m]
    C
    OD
    3541.4
    [m]
    C
    OD
    3542.1
    [m]
    C
    OD
    3542.2
    [m]
    C
    OD
    3542.4
    [m]
    C
    OD
    3548.0
    [m]
    DC
    STATOIL
    3552.0
    [m]
    C
    OD
    3563.0
    [m]
    DC
    STATOIL
    3565.0
    [m]
    C
    OD
    3572.0
    [m]
    C
    OD
    3572.0
    [m]
    DC
    RRI
    3578.0
    [m]
    DC
    STATOIL
    3583.0
    [m]
    C
    OD
    3593.0
    [m]
    DC
    STATOIL
    3596.0
    [m]
    C
    OD
    3596.0
    [m]
    C
    OD
    3608.0
    [m]
    DC
    STATOIL
    3623.0
    [m]
    DC
    STATOI
    3637.0
    [m]
    C
    OD
    3638.0
    [m]
    DC
    STATOIL
    3652.0
    [m]
    C
    OD
    3683.0
    [m]
    DC
    RRI
    3688.0
    [m]
    DC
    OD
    3690.0
    [m]
    DC
    OD
    3693.0
    [m]
    DC
    OD
    3695.0
    [m]
    DC
    OD
    3710.0
    [m]
    DC
    OD
    3725.0
    [m]
    DC
    OD
    3764.0
    [m]
    DC
    RRI
    3770.0
    [m]
    DC
    OD
    3794.0
    [m]
    DC
    OD
    3824.0
    [m]
    DC
    RRI
    3923.0
    [m]
    DC
    RRI
    3975.0
    [m]
    DC
    OD
    3983.0
    [m]
    DC
    RRI
    4043.0
    [m]
    DC
    RRI
    4087.1
    [m]
    C
    OD
    4088.3
    [m]
    C
    OD

  • 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
    DST2A
    3445.00
    3471.50
    25.05.1981 - 15:40
    YES

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.72

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    1.98
    pdf
    1.93
    pdf
    1.84
    pdf
    1.89
    pdf
    1.89
    pdf
    1.25
    pdf
    2.00
    pdf
    1.89
    pdf
    1.74
    pdf
    2.00
    pdf
    0.10

  • 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
    4.29

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    2.0
    3445
    3471
    14.3
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    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]
    2.0
    84
    688000
    0.778
    0.620
    8190

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL
    1850
    3574
    CBL
    2300
    3756
    CBL
    3388
    3566
    CST
    2721
    3780
    CST
    3781
    4080
    DLL MSFL GR
    2650
    3797
    FDC CNL GR
    874
    2382
    FDC CNL GR
    2368
    3798
    HDT
    2368
    3791
    HDT
    3756
    4085
    ISF BHC GR
    2320
    3800
    ISF LSS GR
    874
    2382
    ISF MSFL BHC GR
    3700
    4084
    LDL CNL GR
    3756
    4085
    NGS
    3200
    3650
    RFT
    2368
    3798
    RFT
    3446
    3548
    RFT
    3859
    3878
    VSP WST
    2367
    3798
    WST
    888
    2382
    WST
    3640
    4084

  • 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
    456.0
    36
    457.0
    0.00
    LOT
    SURF.COND.
    20
    873.0
    26
    879.0
    1.63
    LOT
    INTERM.
    13 3/8
    2367.0
    17 1/2
    2383.0
    1.64
    LOT
    INTERM.
    8 5/8
    3756.0
    12 1/4
    3800.0
    1.76
    LOT
    OPEN HOLE
    4089.0
    8 1/2
    4089.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    457
    0.00
    seawater
    879
    1.13
    100.0
    water
    1506
    1.23
    56.0
    water
    1836
    1.25
    50.0
    water
    2000
    1.29
    58.0
    water
    2197
    1.32
    71.0
    water
    2383
    1.28
    55.0
    water
    3200
    1.29
    44.0
    water
    3401
    1.34
    47.0
    water
    3417
    1.35
    70.0
    water
    3458
    1.40
    42.0
    water
    3478
    1.37
    50.0
    water
    3518
    1.38
    43.0
    water
    3800
    1.36
    47.0
    water
    4089
    1.43
    56.0
    water

  • Thin sections at the Norwegian Offshore Directorate
    Thin sections at the Norwegian Offshore Directorate
    Depth
    Unit
    3409.98
    [m ]
    3401.78
    [m ]
    3404.80
    [m ]
    3405.85
    [m ]
    3405.88
    [m ]
    3406.48
    [m ]
    3407.20
    [m ]
    3408.25
    [m ]
    3400.75
    [m ]
    3410.00
    [m ]
    3410.70
    [m ]
    3411.98
    [m ]
    3413.98
    [m ]
    3447.30
    [m ]
    3448.60
    [m ]
    3449.75
    [m ]
    3450.77
    [m ]
    3450.80
    [m ]
    3451.80
    [m ]
    3452.83
    [m ]
    3454.84
    [m ]
    3455.95
    [m ]
    3455.98
    [m ]
    3456.96
    [m ]
    3457.35
    [m ]
    3457.40
    [m ]
    3458.96
    [m ]
    3459.58
    [m ]
    3459.88
    [m ]
    3460.99
    [m ]
    3462.25
    [m ]
    3463.20
    [m ]
    3464.15
    [m ]
    3465.00
    [m ]
    3466.50
    [m ]
    3467.70
    [m ]
    3468.95
    [m ]
    3469.30
    [m ]
    3470.50
    [m ]
    3471.23
    [m ]
    3472.30
    [m ]
    3473.00
    [m ]
    3474.00
    [m ]
    3474.05
    [m ]
    3475.70
    [m ]
    3475.76
    [m ]
    3477.32
    [m ]
    3477.36
    [m ]
    3478.10
    [m ]
    3479.72
    [m ]
    3480.23
    [m ]
    3481.05
    [m ]
    3481.08
    [m ]
    3482.20
    [m ]
    3483.70
    [m ]
    3485.75
    [m ]
    3486.75
    [m ]
    3487.72
    [m ]
    3487.76
    [m ]
    3488.60
    [m ]
    3492.40
    [m ]
    3493.25
    [m ]
    3494.45
    [m ]
    3494.88
    [m ]
    3495.20
    [m ]
    3496.40
    [m ]
    3497.95
    [m ]
    3499.00
    [m ]
    3500.15
    [m ]
    3501.15
    [m ]
    3502.30
    [m ]
    3503.35
    [m ]
    3504.55
    [m ]
    3505.23
    [m ]
    3505.33
    [m ]
    3506.20
    [m ]
    3506.30
    [m ]
    3507.05
    [m ]
    3509.05
    [m ]
    3510.30
    [m ]
    3510.35
    [m ]
    3510.88
    [m ]
    3511.08
    [m ]
    3511.12
    [m ]
    3511.65
    [m ]
    3511.70
    [m ]
    3513.70
    [m ]
    3514.75
    [m ]
    3518.75
    [m ]
    3519.68
    [m ]
    3519.78
    [m ]
    3520.65
    [m ]
    3521.00
    [m ]
    3539.80
    [m ]
    3522.30
    [m ]
    3523.75
    [m ]
    3523.90
    [m ]
    3524.85
    [m ]
    3526.00
    [m ]
    3527.35
    [m ]
    3528.70
    [m ]
    3529.70
    [m ]
    3530.60
    [m ]
    3536.15
    [m ]
    3537.28
    [m ]
    3538.60
    [m ]
    4088.30
    [m ]
    3542.20
    [m ]
    4087.10
    [m ]
    3525.00
    [m ]
    3512.70
    [m ]
    3521.06
    [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