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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6407/1-3

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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.
    6407/1-3
    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.
    6407/1-3
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    ST 8110 - 435 SP 140
    Production licence
    Official designation of the production licence the wellbore was drilled or planned to be drilled from ( well head posistion).
    Drilling operator
    Name of the licensee starting the drilling operation on behalf of the active production license (well head position). This will usually equal the operator of the production license.
    Den norske stats oljeselskap a.s
    Drill permit
    The drilling permit number together with the version of the drilling permit as stated in the drilling permit granted by the Norwegian Offshore Directorate.
    388-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.
    122
    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,
    17.09.1983
    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.
    16.01.1984
    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.
    16.01.1986
    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.
    13.12.2005
    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.
    OIL/GAS
    Discovery wellbore
    Indicator which tells if the wellbore made a new discovery. Legal values: YES, NO. Prior to press-release or other information regarding drilling results, the indicator will be “NO” as a default.
    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.
    FANGST GP
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    29.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    286.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4469.0
    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).
    4467.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    4.2
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    153
    Oldest penetrated age
    Age (according to Geologic Time Scale 2004 by F. M. Gradstein, et al. (2004)) of the oldest penetrated formation. May differ from age at TD for example in deviated wellbores. Examples of legal values: CRETACEOUS, EARLY CRETACEOUS, LATE JURASSIC, EARLY PERMIAN, EARLY TRIASSIC, EOCENE.
    LATE TRIASSIC
    Oldest penetrated formation
    Name of the oldest lithostratigraphic unit penetrated by the wellbore. Shown only for released wells. In most wellbores this is formation or group at total depth. May differ from formation or group at TD for example in wellbores drilled with high deviation or through faults. Examples of legal values: AMUNDSEN FM, BALDER FM, BASEMENT, BLODØKS FM, BRYNE FM, BURTON FM, COOK FM, DRAKE FM, DRAUPNE FM, EKOFISK FM, DUNLIN GP.
    GREY BEDS (INFORMAL)
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    64° 52' 25.48'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    7° 2' 53.47'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7195989.53
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    407531.49
    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.
    29

  • Wellbore history
    General
    Wildcat well 6407/1-3 was drilled in the Haltenbanken area off shore Mid Norway. It is situated on a separate but related structure to 6407/1-2, which found gas-condensate in the Middle Jurassic Garn Formation. The primary target of well 6407/1-3 was Middle Jurassic sandstones. Secondary target was Early Jurassic sandstones. Other zones of interest were the Late and Early Cretaceous and the coal unit in the Early Jurassic.
    The well is Type Well for the Brygge Formation and Reference Well for the Hordaland Group, it is Type Well for the Garn Formation, and it is Reference Well for the Ile and Not Formations.
    Operations and results
    Wildcat well 6407/1-3 was spudded with the semi-submersible installation Dyvi Delta on 17 September 1983 and drilled to TD at 4469 m in Late Triassic sediments of the Åre Formation. Hole problems occurred when running back in the hole after a period of bad weather. The hole had collapsed and had to be reamed back to bottom at 3136 M. A drilling break occurred at 3746 to 3748 m. All in all, there was a total of 16 days downtime caused by bad weather. Still, the well was drilled 22 days faster than prognosed. This was mainly due to fast penetration in the 17 1/2" and 6" hole, an efficient coring operation and favourable weather conditions compared to well 6407/1-2. The well was drilled with seawater/gel down to 948 m, with lignosulphonate/gypsum from 948 m to 3608 m, and with bentonite gel from 3608 m to TD.
    Hydrocarbon bearing Middle Jurassic sandstones (Garn Formation) were encountered at 3600 m. A gas cap extended to 3687.5 m followed by an oil zone down to 3709 m. At this point the sand grades rapidly into the underlying silt and clay of the Not Formation at 3709.5 m. This makes it difficult to conclude on an OWC for the discovery. The Nise Formation from 2448 m to 2601 m had good gas shows whilst drilling and oil contamination of drilling mud. Mud log data suggested a possible light oil accumulation with associated gas and an oil water contact at approximately 2560 m. Reservoir properties were however poor with a lithology consisting of siltstone grading to very fine sandstone interbedded with claystone. Hydrocarbon shows were also recorded in zones in the Early Cretaceous and in the lower parts of the "Coal Unit". None of these zones were of good reservoir quality. The Early Jurassic sandstones showed only traces of hydrocarbons. No good source rocks were found above base Cretaceous. Late Jurassic shales from 3521 m to 3545 m had excellent source potential with type II/III kerogen and TOC in the range 3 -7%. Hydrogen Index was typically 400 - 500 mg HC/g TOC and the shales had reached early oil window maturity. Also Early Jurassic shales and coals has potential for light oils and gas.
    Seven cores were cut in the Middle Jurassic sandstones from 3619 m to 3717 m and from 3748 m to 3758 m. RFT pressure points were sampled over the Middle to Early Jurassic sandstone sequences. Three RFT fluid samples were taken at 3695 m, 3692 m, and at 3676.2 m.
    The well was permanently abandoned on 16 January 1984 as an oil and gas discovery.
    Testing
    Two drill stem tests were performed in the Middle Jurassic sandstone in the oil zone from 3697.5 - 3702.5 m and in the gas zone from 3665 - 3670 m. DST1 produced 396.1 Sm3 oil and 58430 Sm3 gas per day, with a gas/oil ratio of 148 Sm3/Sm3. DST2 produced 191.8 Sm3 oil and 725400 gas per day, with a gas/oil ratio of 3782 Sm3/Sm3.

  • 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]
    420.00
    4467.50

  • 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
    3619.0
    3619.7
    [m ]
    2
    3621.0
    3639.0
    [m ]
    3
    3639.0
    3657.7
    [m ]
    4
    3657.0
    3684.0
    [m ]
    5
    3684.0
    3710.4
    [m ]
    6
    3711.0
    3716.2
    [m ]
    7
    3748.0
    3758.0
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    106.0
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 3619-3624m
    Core photo at depth: 3624-3628m
    Core photo at depth: 3628-3632m
    Core photo at depth: 3632-3636m
    Core photo at depth: 3636-3640m
    3619-3624m
    3624-3628m
    3628-3632m
    3632-3636m
    3636-3640m
    Core photo at depth: 3640-3644m
    Core photo at depth: 3644-3648m
    Core photo at depth: 3648-3652m
    Core photo at depth: 3652-3656m
    Core photo at depth: 3656-3658m
    3640-3644m
    3644-3648m
    3648-3652m
    3652-3656m
    3656-3658m
    Core photo at depth: 3659-3663m
    Core photo at depth: 3663-3667m
    Core photo at depth: 3667-3671m
    Core photo at depth: 3671-3675m
    Core photo at depth: 3675-3679m
    3659-3663m
    3663-3667m
    3667-3671m
    3671-3675m
    3675-3679m
    Core photo at depth: 3679-3683m
    Core photo at depth: 3683-3687m
    Core photo at depth: 3687-3691m
    Core photo at depth: 3691-3695m
    Core photo at depth: 3695-3699m
    3679-3683m
    3683-3687m
    3687-3691m
    3691-3695m
    3695-3699m
    Core photo at depth: 3699-3703m
    Core photo at depth: 3703-3707m
    Core photo at depth: 3707-3711m
    Core photo at depth: 3711-3715m
    Core photo at depth: 3715-3750m
    3699-3703m
    3703-3707m
    3707-3711m
    3711-3715m
    3715-3750m
    Core photo at depth: 3750-3754m
    Core photo at depth: 3754-3758m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    3750-3754m
    3754-3758m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    2110.0
    [m]
    DC
    LAP
    2190.0
    [m]
    DC
    LAP
    2215.0
    [m]
    DC
    LAP
    2230.0
    [m]
    DC
    LAP
    2245.0
    [m]
    DC
    LAP
    2260.0
    [m]
    DC
    LAP
    2275.0
    [m]
    DC
    LAP
    2290.0
    [m]
    DC
    LAP
    2305.0
    [m]
    DC
    LAP
    2333.0
    [m]
    SWC
    LAP
    2335.0
    [m]
    DC
    LAP
    2339.9
    [m]
    SWC
    LAP
    2365.0
    [m]
    DC
    LAP
    2367.0
    [m]
    SWC
    LAP
    2380.0
    [m]
    DC
    LAP
    2440.0
    [m]
    DC
    LAP
    2455.0
    [m]
    SWC
    LAP
    2470.0
    [m]
    DC
    LAP
    2476.0
    [m]
    SWC
    LAP
    2507.0
    [m]
    SWC
    LAP
    2515.0
    [m]
    DC
    LAP
    2521.9
    [m]
    SWC
    LAP
    2526.0
    [m]
    SWC
    LAP
    2537.0
    [m]
    SWC
    LAP
    2546.0
    [m]
    SWC
    LAP
    2555.0
    [m]
    SWC
    LAP
    2565.0
    [m]
    SWC
    LAP
    2570.0
    [m]
    DC
    LAP
    2579.9
    [m]
    SWC
    LAP
    2585.0
    [m]
    DC
    LAP
    2585.0
    [m]
    SWC
    LAP
    2600.0
    [m]
    DC
    LAP
    2615.0
    [m]
    DC
    LAP
    2630.0
    [m]
    DC
    LAP
    2645.0
    [m]
    DC
    LAP
    2660.0
    [m]
    DC
    LAP
    2675.0
    [m]
    DC
    LAP
    2690.0
    [m]
    DC
    LAP
    2695.0
    [m]
    SWC
    LAP
    2705.0
    [m]
    DC
    LAP
    2720.0
    [m]
    DC
    LAP
    2735.0
    [m]
    DC
    LAP
    2750.0
    [m]
    DC
    LAP
    2765.0
    [m]
    DC
    LAP
    2780.0
    [m]
    DC
    LAP
    2795.0
    [m]
    DC
    LAP
    2810.0
    [m]
    DC
    LAP
    2825.0
    [m]
    DC
    LAP
    2840.0
    [m]
    DC
    LAP
    2855.0
    [m]
    DC
    LAP
    2870.0
    [m]
    SWC
    LAP
    2885.0
    [m]
    DC
    LAP
    2900.0
    [m]
    DC
    LAP
    2915.0
    [m]
    DC
    LAP
    2930.0
    [m]
    DC
    LAP
    2945.0
    [m]
    DC
    LAP
    2960.0
    [m]
    DC
    LAP
    2975.0
    [m]
    DC
    LAP
    2990.0
    [m]
    DC
    LAP
    3005.0
    [m]
    DC
    LAP
    3020.0
    [m]
    DC
    LAP
    3035.0
    [m]
    DC
    LAP
    3040.0
    [m]
    DC
    LAP
    3050.0
    [m]
    DC
    LAP
    3065.0
    [m]
    DC
    LAP
    3080.0
    [m]
    DC
    LAP
    3090.0
    [m]
    SWC
    LAP
    3095.0
    [m]
    DC
    LAP
    3110.0
    [m]
    DC
    LAP
    3125.0
    [m]
    DC
    LAP
    3155.0
    [m]
    DC
    LAP
    3160.0
    [m]
    SWC
    LAP
    3170.0
    [m]
    DC
    LAP
    3185.0
    [m]
    DC
    LAP
    3195.0
    [m]
    SWC
    LAP
    3200.0
    [m]
    DC
    LAP
    3215.0
    [m]
    DC
    LAP
    3230.0
    [m]
    DC
    LAP
    3230.0
    [m]
    SWC
    LAP
    3245.0
    [m]
    DC
    LAP
    3260.0
    [m]
    DC
    LAP
    3275.0
    [m]
    DC
    LAP
    3280.0
    [m]
    SWC
    LAP
    3290.0
    [m]
    DC
    LAP
    3305.0
    [m]
    DC
    LAP
    3320.0
    [m]
    DC
    LAP
    3335.0
    [m]
    DC
    LAP
    3350.0
    [m]
    DC
    LAP
    3365.0
    [m]
    DC
    LAP
    3380.0
    [m]
    DC
    LAP
    3395.0
    [m]
    DC
    LAP
    3410.0
    [m]
    DC
    LAP
    3424.0
    [m]
    SWC
    LAP
    3425.0
    [m]
    DC
    LAP
    3440.0
    [m]
    DC
    LAP
    3455.0
    [m]
    DC
    LAP
    3462.0
    [m]
    SWC
    LAP
    3464.9
    [m]
    SWC
    LAP
    3470.0
    [m]
    SWC
    LAP
    3470.0
    [m]
    DC
    LAP
    3484.0
    [m]
    SWC
    LAP
    3485.0
    [m]
    DC
    LAP
    3495.1
    [m]
    SWC
    LAP
    3499.0
    [m]
    SWC
    LAP
    3500.0
    [m]
    DC
    LAP
    3530.0
    [m]
    DC
    LAP
    3545.0
    [m]
    DC
    LAP
    3560.0
    [m]
    DC
    LAP
    3575.0
    [m]
    DC
    LAP
    3590.0
    [m]
    DC
    LAP
    3598.0
    [m]
    SWC
    LAP
    3599.0
    [m]
    SWC
    LAP
    3605.0
    [m]
    DC
    LAP
    3619.0
    [m]
    C
    LAP
    3620.0
    [m]
    DC
    LAP
    3621.0
    [m]
    C
    LAP
    3630.9
    [m]
    C
    LAP
    3642.5
    [m]
    C
    LAP
    3645.0
    [m]
    C
    LAP
    3653.6
    [m]
    C
    LAP
    3666.1
    [m]
    C
    LAP
    3667.2
    [m]
    C
    LAP
    3689.3
    [m]
    DC
    LAP
    3689.6
    [m]
    DC
    LAP
    3693.4
    [m]
    C
    LAP
    3693.5
    [m]
    C
    RRI
    3698.3
    [m]
    DC
    LAP
    3704.5
    [m]
    C
    LAP
    3704.6
    [m]
    C
    LAP
    3704.7
    [m]
    C
    LAP
    3705.5
    [m]
    C
    LAP
    3709.4
    [m]
    C
    LAP
    3709.7
    [m]
    C
    LAP
    3709.7
    [m]
    C
    RRI
    3710.1
    [m]
    C
    LAP
    3711.2
    [m]
    C
    LAP
    3713.8
    [m]
    C
    RRI
    3715.1
    [m]
    C
    LAP
    3715.6
    [m]
    C
    LAP
    3716.1
    [m]
    C
    LAP
    3716.2
    [m]
    C
    RRI
    3717.0
    [m]
    SWC
    LAP
    3725.0
    [m]
    SWC
    LAP
    3730.0
    [m]
    SWC
    LAP
    3733.0
    [m]
    SWC
    LAP
    3735.0
    [m]
    SWC
    LAP
    3739.0
    [m]
    SWC
    LAP
    3744.0
    [m]
    SWC
    LAP
    3748.1
    [m]
    C
    LAP
    3751.0
    [m]
    C
    LAP
    3752.6
    [m]
    C
    LAP
    3756.1
    [m]
    C
    LAP
    3760.0
    [m]
    DC
    LAP
    3775.0
    [m]
    DC
    LAP
    3790.0
    [m]
    DC
    LAP
    3794.0
    [m]
    SWC
    LAP
    3805.0
    [m]
    C
    LAP
    3820.0
    [m]
    C
    LAP
    3835.0
    [m]
    C
    LAP
    3847.0
    [m]
    SWC
    LAP
    3850.0
    [m]
    C
    LAP
    3854.0
    [m]
    SWC
    LAP
    3865.0
    [m]
    C
    LAP
    3880.0
    [m]
    C
    LAP
    3883.0
    [m]
    SWC
    LAP
    3895.0
    [m]
    C
    LAP
    3910.0
    [m]
    C
    LAP
    3915.0
    [m]
    SWC
    LAP
    3925.0
    [m]
    C
    LAP
    3928.0
    [m]
    SWC
    LAP
    3937.0
    [m]
    SWC
    LAP
    3940.0
    [m]
    C
    LAP
    3944.0
    [m]
    SWC
    LAP
    3954.0
    [m]
    SWC
    LAP
    3955.0
    [m]
    C
    LAP
    3963.0
    [m]
    SWC
    LAP
    3970.0
    [m]
    C
    LAP
    3982.0
    [m]
    SWC
    LAP
    3985.0
    [m]
    C
    LAP
    3987.0
    [m]
    SWC
    LAP
    4000.0
    [m]
    C
    LAP
    4015.0
    [m]
    C
    LAP
    4030.0
    [m]
    C
    LAP
    4045.0
    [m]
    C
    LAP
    4047.0
    [m]
    SWC
    LAP
    4060.0
    [m]
    C
    LAP
    4075.0
    [m]
    C
    LAP
    4090.0
    [m]
    C
    LAP
    4092.0
    [m]
    SWC
    LAP
    4105.0
    [m]
    C
    LAP
    4117.9
    [m]
    SWC
    LAP
    4120.0
    [m]
    C
    LAP
    4125.0
    [m]
    SWC
    LAP
    4135.0
    [m]
    C
    LAP
    4150.0
    [m]
    C
    LAP
    4165.0
    [m]
    C
    LAP
    4180.0
    [m]
    C
    LAP
    4195.0
    [m]
    C
    LAP
    4210.0
    [m]
    C
    LAP
    4225.0
    [m]
    C
    LAP
    4240.0
    [m]
    C
    LAP
    4255.0
    [m]
    C
    LAP
    4270.0
    [m]
    C
    LAP
    4285.0
    [m]
    C
    LAP
    4300.0
    [m]
    C
    LAP
    4315.0
    [m]
    C
    LAP
    4330.0
    [m]
    C
    LAP
    4345.0
    [m]
    C
    LAP
    4360.0
    [m]
    C
    LAP
    4375.0
    [m]
    C
    LAP
    4390.0
    [m]
    C
    LAP
    4405.0
    [m]
    C
    LAP
    4420.0
    [m]
    C
    LAP
    4435.0
    [m]
    DC
    LAP
    4450.0
    [m]
    DC
    LAP
    4460.0
    [m]
    DC
    LAP
    4465.0
    [m]
    DC
    LAP
    4467.5
    [m]
    DC
    LAP

  • 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
    TEST1
    3697.50
    3702.50
    22.12.1983 - 00:00
    YES
    DST
    TEST2
    3665.00
    3670.00
    04.01.1984 - 00:00
    YES

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.81

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    1.03
    pdf
    1.20
    pdf
    0.25
    pdf
    5.46
    pdf
    0.65
    pdf
    1.06

  • 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
    38.11
    pdf
    4.48
    pdf
    4.26
    pdf
    87.24
    pdf
    18.62
    pdf
    22.11
    pdf
    5.62
    pdf
    2.26
    pdf
    1.23
    pdf
    2.16
    pdf
    7.20
    pdf
    3.08
    pdf
    6.79
    pdf
    5.95
    pdf
    4.73
    pdf
    8.94
    pdf
    1.12
    pdf
    1.24
    pdf
    2.34
    pdf
    1.52
    pdf
    1.23
    pdf
    1.47
    pdf
    10.02
    pdf
    1.20
    pdf
    1.28
    pdf
    1.27
    pdf
    1.16

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    3698
    3703
    19.1
    2.0
    3665
    3670
    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
    137
    867000
    0.872
    0.665
    158
    2.0
    253
    875000
    0.776
    0.655
    3458

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL VDL GR
    1980
    2280
    CBL VDL GR
    3082
    3595
    CBL VDL GR
    3385
    4469
    CST
    2333
    3598
    CST
    3597
    3963
    CST
    3982
    4469
    DLL MSFL SP GR
    3595
    3976
    ISF BHC MSFL SP GR
    3964
    4469
    ISF BHC SP GR
    3595
    3976
    ISF LSS MSFL SP GR
    315
    3606
    LDL CNL GR
    3596
    3975
    LDL CNL NGL
    2288
    3601
    LDL GR
    947
    2297
    MWD - GR RES DIR
    2280
    3970
    NGT
    3300
    3600
    NGT
    3595
    3976
    RFT GR
    2288
    3467
    RFT GR
    3393
    4024
    RFT GR
    3595
    3950
    SHDT GR
    2288
    3608
    SHDT GR
    3595
    3976
    SHDT GR
    3964
    4469
    TEMP
    795
    4469
    VSP
    595
    4469

  • 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
    415.0
    36
    415.0
    0.00
    LOT
    SURF.COND.
    20
    948.0
    26
    965.0
    1.70
    LOT
    INTERM.
    13 3/8
    2286.0
    17 1/2
    2300.0
    1.87
    LOT
    INTERM.
    9 5/8
    3595.0
    12 1/4
    3608.0
    1.82
    LOT
    LINER
    7
    3969.0
    8 1/2
    3976.0
    0.00
    LOT
    OPEN HOLE
    4469.0
    6
    4469.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    450
    1.08
    66.0
    WATER BASED
    575
    1.09
    50.0
    WATER BASED
    670
    1.10
    60.0
    WATER BASED
    920
    1.11
    47.0
    WATER BASED
    1040
    1.08
    44.0
    WATER BASED
    1210
    1.12
    45.0
    WATER BASED
    1380
    1.15
    47.0
    WATER BASED
    1480
    1.16
    47.0
    WATER BASED
    1610
    1.15
    44.0
    WATER BASED
    1800
    1.27
    44.0
    WATER BASED
    1890
    1.40
    55.0
    WATER BASED
    2205
    1.55
    58.0
    WATER BASED
    2310
    1.66
    WATER BASED
    2525
    1.66
    51.0
    WATER BASED
    2600
    1.70
    48.0
    WATER BASED
    3720
    1.20
    55.0
    WATER BASED
    4320
    1.30
    73.0
    WATER BASED
    4450
    1.29
    77.0
    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
    0.28