Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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19.07.2024 - 01:27
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3/7-4

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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.
    3/7-4
    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).
    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.
    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.
    3/7-4
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    EL 8201 - 219 SP 220
    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.
    A/S Norske Shell
    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.
    619-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.
    126
    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,
    20.09.1989
    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.
    23.01.1990
    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.
    23.01.1992
    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.
    19.10.2006
    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.
    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.
    SANDNES 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.
    MIDDLE JURASSIC
    2nd level with HC, formation
    Name of lithostartigraphic unit, 2nd level, where hydrocarbons were encountered. Shown only for released wells. Examples of legal values: BASEMENT, COOK FM, EKOFISK FM, HEIMDAL FM, SANDNES FM, SOGNEFJORD FM, TARBERT FM, BRENT GP.
    BRYNE 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.
    66.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3723.0
    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).
    3721.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    7.3
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    136
    Oldest penetrated age
    Age (according to Geologic Time Scale 2004 by F. M. Gradstein, et al. (2004)) of the oldest penetrated formation. May differ from age at TD for example in deviated wellbores. Examples of legal values: CRETACEOUS, EARLY CRETACEOUS, LATE JURASSIC, EARLY PERMIAN, EARLY TRIASSIC, EOCENE.
    LATE PERMIAN
    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.
    ZECHSTEIN GP
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    56° 24' 15.6'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    4° 14' 22.24'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6251910.40
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    576498.02
    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.
    1467
  • Wellbore history

    General
    Well 3/7-4 was designed to drill a prospect on the Lulita culmination. The Lulita prospect extends in to Danish waters, and forms part of an elongated, N-S trending, salt induced feature on the western margin of the Søgne Basin. The present structural features were developed during mid Cretaceous time, and closure at Late Cretaceous and Tertiary levels essentially reflects compaction and drape over the Jurassic high. The Jurassic Lulita closure is separated from the area tested by the 3/7-3 well by a faulted saddle, which also is well expressed at Tertiary and Cretaceous levels, providing a vertical closure of some 75 metres. The well had as primary objective to test the hydrocarbon potential of Middle Jurassic sandstones within a structural/stratigraphic trap, and as secondary objective to testing the potential in possible Late Jurassic and Early Cretaceous sandstones, within a structural trap. Additional objectives included testing of Late Cretaceous Chalk, found hydrocarbon bearing in the nearby Harald field, Paleocene/Eocene turbiditic sandstones, and the reservoir quality of the Triassic sequence. The well should drill some 150 m into rocks of Triassic age. Shallow gas could be encountered at 317 to 388 m, at 485, and at 515 m according to seismic anomalies.
    Operations and results
    Wildcat well 3/7-4 was spudded with the semi-submersible installation Hunter on 20 September 1989 and drilled to TD at 3723 m in the Permian Zechstein Group. At 3472.9 m the string was backed off, and a cement kick off plug was set. The hole was sidetracked from 3405 m. The well was drilled with seawater and hi-vis spud mud down to 622 m, with KCl polymer from 622 m to 3473 m, and with seawater/polymer from 3473 m to TD. No shallow gas was encountered.
    A 160 m hydrocarbon column from top Ula Formation and down to 3572 m in the Bryne Formation was found from well-logs, core shows, and RFT pressure gradients. Strong shows were recorded throughout the reservoir. Below the ODT shows died out, and were not seen below 3600 m. The RFT pressures indicated a light condensate-type fluid gradient of 0.39 bar/10m in the hydrocarbon-bearing zone. The secondary and additional objective levels were evaluated: A 29 m thick sequence of Maureen Formation sandstone was encountered in the Tertiary, no reservoir quality sands or chalk was found in the Late Jurassic and Cretaceous, and the Triassic was missing. Weak shows were recorded in the Maureen sandstone.
    Two segregated RFT fluid samples were obtained. The first (No. 1) from 3564.5 m contained gas, condensate and water, whilst the second (No. 2) from 3442.5 m contained gas and water only. A total of 123.5 m conventional core was recovered in eight cores in the interval 3416 m to 3574 in the Ula and Bryne Formations. Core no 1 was cut in the first hole, the remaining seven cores were cut in the sidetrack.
    The well was permanently abandoned on 23 January 1990 as a gas/condensate discovery.
    Testing
    Two DST tests were performed in this well. Test no 1A in the interval 3473 to 3537 m produced 665 Sm3/d liquid hydrocarbons of  0.804 g/cm3 and 884450 Sm3 gas through  a 19 mm choke. The Gas/Liquid ratio was 1330 Sm3/Sm3. Test no 1B in the interval 3440 to 3537 m produced 611 Sm3/d of 0.796 g/cm3 liquid and 838292 Sm3 gas through a 19 mm choke.  The GLR was 1372 Sm3/Sm3. The gas gravity (air = 1) was 0.72 in both tests. Temperature measurements during the tests gave a reservoir temperature of 131 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]
    630.00
    3721.00
  • 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
    3416.0
    3436.0
    [m ]
    2
    3437.0
    3464.7
    [m ]
    3
    3464.4
    3487.9
    [m ]
    4
    3492.0
    3501.2
    [m ]
    5
    3504.0
    3514.0
    [m ]
    6
    3514.0
    3520.0
    [m ]
    7
    3526.0
    3553.4
    [m ]
    8
    3553.4
    3574.3
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    144.7
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES
  • Core photos

    Core photos
    Core photo at depth: 3416-3421m
    Core photo at depth: 3421-3426m
    Core photo at depth: 3426-3431m
    Core photo at depth: 3431-3434m
    Core photo at depth: 3437-3442m
    3416-3421m
    3421-3426m
    3426-3431m
    3431-3434m
    3437-3442m
    Core photo at depth: 3442-3447m
    Core photo at depth: 3447-3452m
    Core photo at depth: 3452-3457m
    Core photo at depth: 3457-3462m
    Core photo at depth: 3462-3465m
    3442-3447m
    3447-3452m
    3452-3457m
    3457-3462m
    3462-3465m
    Core photo at depth: 3464-3469m
    Core photo at depth: 3469-3474m
    Core photo at depth: 3474-3479m
    Core photo at depth: 3479-3484m
    Core photo at depth: 3484-3487m
    3464-3469m
    3469-3474m
    3474-3479m
    3479-3484m
    3484-3487m
    Core photo at depth: 3492-3497m
    Core photo at depth: 3497-3501m
    Core photo at depth: 3504-3509m
    Core photo at depth: 3509-3514m
    Core photo at depth: 3514-3519m
    3492-3497m
    3497-3501m
    3504-3509m
    3509-3514m
    3514-3519m
    Core photo at depth: 3519-3524m
    Core photo at depth: 3524-3525m
    Core photo at depth: 3526-3531m
    Core photo at depth: 3531-3536m
    Core photo at depth: 3536-3541m
    3519-3524m
    3524-3525m
    3526-3531m
    3531-3536m
    3536-3541m
    Core photo at depth: 3541-3546m
    Core photo at depth: 3546-3551m
    Core photo at depth: 3551-3553m
    Core photo at depth: 3553-3558m
    Core photo at depth: 3558-3563m
    3541-3546m
    3546-3551m
    3551-3553m
    3553-3558m
    3558-3563m
    Core photo at depth: 3563-3568m
    Core photo at depth: 3568-3573m
    Core photo at depth: 3573-3574m
    Core photo at depth:  
    Core photo at depth:  
    3563-3568m
    3568-3573m
    3573-3574m
  • Palynological slides at the Norwegian Offshore Directorate

    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1980.0
    [m]
    DC
    RRI
    1980.0
    [m]
    DC
    AMOCO
    2010.0
    [m]
    DC
    RRI
    2010.0
    [m]
    DC
    AMOCO
    2040.0
    [m]
    DC
    RRI
    2040.0
    [m]
    DC
    AMOCO
    2070.0
    [m]
    DC
    RRI
    2070.0
    [m]
    DC
    AMOCO
    2080.0
    [m]
    DC
    RRI
    2090.0
    [m]
    DC
    RRI
    2100.0
    [m]
    DC
    RRI
    2100.0
    [m]
    DC
    AMOCO
    2120.0
    [m]
    DC
    RRI
    2130.0
    [m]
    DC
    RRI
    2130.0
    [m]
    DC
    AMOCO
    2140.0
    [m]
    DC
    RRI
    2160.0
    [m]
    DC
    RRI
    2160.0
    [m]
    DC
    AMOCO
    2170.0
    [m]
    DC
    RRI
    2180.0
    [m]
    DC
    RRI
    2190.0
    [m]
    DC
    RRI
    2190.0
    [m]
    DC
    AMOCO
    2200.0
    [m]
    DC
    RRI
    2210.0
    [m]
    DC
    RRI
    2220.0
    [m]
    DC
    RRI
    2220.0
    [m]
    DC
    AMOCO
    2240.0
    [m]
    DC
    RRI
    2250.0
    [m]
    DC
    RRI
    2250.0
    [m]
    DC
    AMOCO
    2260.0
    [m]
    DC
    RRI
    2280.0
    [m]
    DC
    RRI
    2280.0
    [m]
    DC
    AMOCO
    2290.0
    [m]
    DC
    RRI
    2300.0
    [m]
    DC
    RRI
    2310.0
    [m]
    DC
    RRI
    2310.0
    [m]
    DC
    AMOCO
    2320.0
    [m]
    DC
    RRI
    2330.0
    [m]
    DC
    RRI
    2340.0
    [m]
    DC
    RRI
    2340.0
    [m]
    DC
    AMOCO
    2360.0
    [m]
    DC
    RRI
    2370.0
    [m]
    DC
    RRI
    2370.0
    [m]
    DC
    AMOCO
    2380.0
    [m]
    DC
    RRI
    2400.0
    [m]
    DC
    RRI
    2400.0
    [m]
    DC
    RRI
    2400.0
    [m]
    DC
    RRI
    2410.0
    [m]
    DC
    RRI
    2420.0
    [m]
    DC
    RRI
    2430.0
    [m]
    DC
    RRI
    2430.0
    [m]
    DC
    AMOCO
    2440.0
    [m]
    DC
    RRI
    2450.0
    [m]
    DC
    RRI
    2460.0
    [m]
    DC
    RRI
    2460.0
    [m]
    DC
    AMOCO
    2480.0
    [m]
    DC
    RRI
    2490.0
    [m]
    DC
    RRI
    2490.0
    [m]
    DC
    AMOCO
    2500.0
    [m]
    DC
    RRI
    2520.0
    [m]
    DC
    RRI
    2520.0
    [m]
    DC
    AMOCO
    2540.0
    [m]
    DC
    RRI
    2550.0
    [m]
    DC
    RRI
    2550.0
    [m]
    DC
    AMOCO
    2560.0
    [m]
    DC
    RRI
    2570.0
    [m]
    DC
    RRI
    2580.0
    [m]
    DC
    RRI
    2580.0
    [m]
    DC
    AMOCO
    2600.0
    [m]
    DC
    RRI
    2610.0
    [m]
    DC
    RRI
    2610.0
    [m]
    DC
    AMOCO
    2620.0
    [m]
    DC
    RRI
    2640.0
    [m]
    DC
    RRI
    2640.0
    [m]
    DC
    AMOCO
    2650.0
    [m]
    DC
    RRI
    2660.0
    [m]
    DC
    RRI
    2670.0
    [m]
    DC
    RRI
    2670.0
    [m]
    DC
    AMOCO
    2680.0
    [m]
    DC
    RRI
    2690.0
    [m]
    DC
    RRI
    2700.0
    [m]
    DC
    RRI
    2700.0
    [m]
    DC
    AMOCO
    2710.0
    [m]
    DC
    RRI
    2720.0
    [m]
    DC
    RRI
    2730.0
    [m]
    DC
    RRI
    2740.0
    [m]
    DC
    RRI
    2750.0
    [m]
    DC
    RRI
    2760.0
    [m]
    DC
    RRI
    2770.0
    [m]
    DC
    RRI
    2780.0
    [m]
    DC
    RRI
    2780.0
    [m]
    DC
    RRI
    2790.0
    [m]
    DC
    RRI
    2790.0
    [m]
    DC
    AMOCO
    2800.0
    [m]
    DC
    RRI
    2800.0
    [m]
    DC
    AMOCO
    2810.0
    [m]
    DC
    RRI
    2810.0
    [m]
    DC
    AMOCO
    2820.0
    [m]
    DC
    RRI
    2820.0
    [m]
    DC
    AMOCO
    2830.0
    [m]
    DC
    RRI
    2830.0
    [m]
    DC
    AMOCO
    2840.0
    [m]
    DC
    RRI
    2840.0
    [m]
    DC
    AMOCO
    2850.0
    [m]
    DC
    RRI
    2850.0
    [m]
    DC
    AMOCO
    2860.0
    [m]
    DC
    RRI
    2860.0
    [m]
    DC
    AMOCO
    2880.0
    [m]
    DC
    RRI
    2890.0
    [m]
    DC
    RRI
    2900.0
    [m]
    DC
    RRI
    2920.0
    [m]
    DC
    RRI
    2930.0
    [m]
    DC
    RRI
    2940.0
    [m]
    DC
    RRI
    2960.0
    [m]
    DC
    RRI
    2970.0
    [m]
    DC
    RRI
    2980.0
    [m]
    DC
    RRI
    3000.0
    [m]
    DC
    RRI
    3382.2
    [m]
    C
    APT
    3417.0
    [m]
    C
    APT
    3426.0
    [m]
    C
    APT
    3428.0
    [m]
    C
    APT
    3430.0
    [m]
    C
    APT
    3432.0
    [m]
    C
    APT
    3434.0
    [m]
    C
    APT
    3436.0
    [m]
    C
    APT
    3438.0
    [m]
    C
    APT
    3440.0
    [m]
    C
    APT
    3440.9
    [m]
    C
    APT
    3441.9
    [m]
    C
    APT
    3442.3
    [m]
    C
    APT
    3446.4
    [m]
    C
    APT
    3447.1
    [m]
    C
    APT
    3447.9
    [m]
    C
    APT
    3448.2
    [m]
    C
    APT
    3448.2
    [m]
    C
    APT
    3450.5
    [m]
    C
    APT
    3451.8
    [m]
    C
    APT
    3459.2
    [m]
    C
    APT
    3459.4
    [m]
    C
    APT
    3459.5
    [m]
    C
    APT
    3463.4
    [m]
    C
    APT
    3464.4
    [m]
    C
    APT
    3466.0
    [m]
    C
    APT
    3467.8
    [m]
    C
    APT
    3469.0
    [m]
    C
    APT
    3469.3
    [m]
    C
    APT
    3471.0
    [m]
    C
    APT
    3471.8
    [m]
    C
    APT
    3473.4
    [m]
    C
    APT
    3475.8
    [m]
    C
    APT
    3476.0
    [m]
    C
    APT
    3480.8
    [m]
    C
    APT
    3486.5
    [m]
    C
    APT
    3495.5
    [m]
    C
    APT
    3497.8
    [m]
    C
    APT
    3498.4
    [m]
    C
    APT
    3507.5
    [m]
    C
    APT
    3509.1
    [m]
    C
    APT
    3511.2
    [m]
    C
    APT
    3513.1
    [m]
    C
    APT
    3514.8
    [m]
    C
    APT
    3516.8
    [m]
    C
    APT
    3519.4
    [m]
    C
    APT
    3522.6
    [m]
    C
    APT
    3527.7
    [m]
    C
    APT
    3534.0
    [m]
    C
    APT
    3539.7
    [m]
    C
    APT
    3541.3
    [m]
    C
    APT
    3551.6
    [m]
    C
    APT
    3552.5
    [m]
    C
    APT
    3554.0
    [m]
    C
    APT
    3554.0
    [m]
    C
    APT
    3558.5
    [m]
    C
    APT
    3559.5
    [m]
    C
    APT
    3563.0
    [m]
    C
    APT
    3563.5
    [m]
    C
    APT
    3568.0
    [m]
    C
    APT
    3568.0
    [m]
    C
    APT
    3568.2
    [m]
    C
    APT
    3574.3
    [m]
    C
    APT
  • 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
    DST1A
    3440.00
    3537.00
    01.01.1990 - 00:00
    YES
    DST
    DST1B
    3470.00
    3440.00
    03.01.1990 - 00:00
    YES
  • Lithostratigraphy

  • Geochemical information

    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    5.53
  • 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
    48.76
  • Drill stem tests (DST)

    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    3473
    3537
    19.0
    2.0
    3440
    3473
    19.0
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    131
    2.0
    131
    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
    665
    884450
    0.804
    0.720
    1330
    2.0
    611
    838292
    0.796
    0.720
    1372
  • Logs

    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL VDL CCL GR
    92
    2092
    CBL VDL CCL GR
    1890
    2400
    CBL VDL CCL GR
    3186
    3636
    CDL CNL SPL CAL
    3370
    3723
    CND CNL DISL GR CAL
    575
    2103
    CND CNL SPL CAL
    2092
    3470
    DIFL AC GR
    180
    619
    DIFL AC SP GR
    2070
    3502
    DIFL AC SP GR
    3382
    3722
    DIFL AC SP GR CAL
    545
    2108
    DIPLOG GR
    3150
    3469
    DIPLOG GR
    3393
    3722
    DLL MLL CAL GR
    3382
    3721
    DLL MLL GR
    2091
    3470
    FMT GR
    2825
    3260
    FMT GR
    3415
    3684
    FMT GR
    3443
    3443
    GYRO MULTISHOT
    92
    2055
    GYRO MULTISHOT
    2055
    3640
    MWD - GR RES DIR
    187
    3603
    PLT GR
    3430
    3549
    SWS GR
    627
    2088
    SWS GR
    3404
    3707
    VSP
    2700
    3723
  • 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
    177.0
    36
    187.0
    0.00
    LOT
    INTERM.
    20
    610.0
    26
    622.0
    1.86
    LOT
    INTERM.
    20
    611.0
    26
    622.0
    1.86
    LOT
    INTERM.
    13 3/8
    2093.0
    17 1/2
    2110.0
    1.88
    LOT
    INTERM.
    9 5/8
    3383.0
    12 1/4
    3603.0
    1.95
    LOT
    LINER
    7
    3710.0
    8 3/8
    3723.0
    0.00
    LOT
  • Drilling mud

    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    187
    1.07
    WATER BASED
    346
    1.07
    WATER BASED
    622
    1.32
    50.0
    WATER BASED
    1011
    1.34
    54.0
    WATER BASED
    1182
    1.33
    56.0
    WATER BASED
    1363
    1.33
    53.0
    WATER BASED
    1649
    1.33
    65.0
    WATER BASED
    2110
    1.50
    62.0
    WATER BASED
    2450
    1.50
    53.0
    WATER BASED
    2889
    1.52
    53.0
    WATER BASED
    3068
    1.50
    45.0
    WATER BASED
    3256
    1.52
    40.0
    WATER BASED
    3390
    1.56
    46.0
    WATER BASED
    3405
    1.55
    48.0
    WATER BASED
    3416
    1.55
    38.0
    WATER BASED
    3506
    1.55
    40.0
    WATER BASED
    3571
    1.55
    40.0
    WATER BASED
    3723
    1.53
    53.0
    WATER BASED
    3725
    1.54
    48.0
    WATER BASED
  • Pressure plots

    Pressure plots
    The pore pressure data is sourced from well logs if no other source is specified. In some wells where pore pressure logs do not exist, information from Drill stem tests and kicks have been used. The data has been reported to the NPD, and further processed and quality controlled by IHS Markit.
    Pressure plots
    Document name
    Document format
    Document size [MB]
    pdf
    0.22