Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
24.11.2024 - 01:27
Time of last synchronization with Norwegian Offshore Directorate's internal systems

6507/5-2

Export: PDF icon PDF

  • General information
    General information
    Attribute Value
    Wellbore name
    Official name of wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    6507/5-2
    Type
    Wellbore type. Legal values: EXPLORATION, DEVELOPMENT, OTHER (see 'Purpose' for more information)
    EXPLORATION
    Purpose
    Final classification of the wellbore.

    Legal values for exploration wellbores:
    WILDCAT, APPRAISAL, WILDCAT-CCS, APPRAISAL-CCS.

    Legal values for development wellbores:
    OBSERVATION, PRODUCTION, INJECTION, INJECTION-CCS, OBSERVATION-CCS.

    Legal values for other wellbores:
    SOIL DRILLING (drilling in connection with track surveys and other subsurface surveys to investigate the soil conditions prior to placement of facilities),
    SHALLOW GAS (drilling to investigate shallow gas before the first 'real' drilling on the location),
    PILOT (drilling to investigate the geology and fluid connectors for location of the main wellbore),
    SCIENTIFIC (drilling according to Law of Scientific research and exploration),
    STRATIGRAPHIC (driling according to Law of Petroleum activities §2-1).
    APPRAISAL
    Status
    Status for the wellbore. Legal values are:

    BLOWOUT: A blowout has occurred in the well.
    CLOSED: A development wellbore that has been closed in a shorter or longer periode. Also applies to development wellbores where drilling is completed, but production/injection has not yet been reported.
    DRILLING: The well is in the drilling phase - can be active drilling, logging, testing or plugging,
    JUNKED: The drilling operation has been terminated due to technical problems.
    P&A: Exploration: The well is plugged and abandoned, and can not be reentered for further use. Development wells: The production/injection from/to the well is stopped and the well is plugged. The wellhead is removed or else made unavailable for further well operations.
    PLUGGED: The wellbore has been plugged, but the upper parts of the wellbore can be re-used. A sidetrack might be drilled at a later stage.
    PRODUCING: It was produced from the wellbore at the time of the operators last monthly report to the Norwegian Offshore Directorate.
    INJECTING: It was injected to the wellbore at the time of the operators last monthly report to the Norwegian Offshore Directorate.
    PREDRILLED: The upper part of the well has been drilled, usually as part of a batch-drilling campaign covering several wellbores.
    RE-CLASS TO DEV: Exploration wellbore that is reclassified to a development wellbore.
    RE-CLASS TO TEST: Exploration wellbore that is reclassified to test production.
    SUSPENDED: The drilling operation in the wellbore has been temporarily stopped. The current plan is to continue drilling later on.
    P&A
    Factmaps in new window
    Main area
    Name of the area on the Norwegian Continental Shelf where the wellbore is located. Legal values: BARENTS SEA, NORWEGIAN SEA, NORTH SEA.
    NORWEGIAN SEA
    Field
    Name of the field the wellbore is related to.
    Discovery
    Name of the discovery the wellbore is related to.
    Well name
    Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    6507/5-2
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    ANO9802- INLINE 1267 & X-LINE 388
    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.
    Amoco Norway Oil Company
    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.
    962-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.
    42
    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,
    13.08.1999
    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.
    23.09.1999
    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.
    23.09.2001
    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.
    11.04.2003
    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.
    APPRAISAL
    Reentry
    Status whether the wellbore has been re-entered (YES) or not (NO). Re-entered wellbores are not included in the count when wellbores are presented in statistical overviews.
    NO
    Content
    For exploration wellbores, status of discovery.

    Legal values:
    DRY, SHOWS (trace amounts of hydrocarbons), GAS, GAS/CONDENSATE, OIL or OIL/GAS.
    SHOWS (GAS SHOWS, OIL SHOWS or OIL/GAS SHOWS) are detected as fluorescent cut (organic extract), petroleum odour, or visual stain on cuttings or cores, or as increased gas reading on the mud-loggers gas detection equipment.
    Legal values for WILDCAT-CCS and APPRAISAL-CCS: WATER

    For development wellbores, type of produced/injected fluid.
    Legal values:
    WATER, CUTTINGS, NOT AVAILABLE, OIL, GAS/CONDENSATE, OIL/GAS, CO2, GAS, WATER/GAS, NOT APPLICABLE.
    GAS/CONDENSATE
    Discovery wellbore
    Indicator which tells if the wellbore made a new discovery. Legal values: YES, NO. Prior to press-release or other information regarding drilling results, the indicator will be “NO” as a default.
    NO
    1st level with HC, age
    Age of lithostratigraphic unit, 1st level, where hydrocarbons were encountered. Examples of legal values: CRETACEOUS, EARLY CRETACEOUS, LATE JURASSIC, EOCENE. See also Norwegian Offshore Directorate bulletins.
    MIDDLE JURASSIC
    1st level with HC, formation
    Name of lithostartigraphic unit, 1st level, where hydrocarbons were encountered. Shown only for released wells. Examples of legal values: BASEMENT, COOK FM, EKOFISK FM, HEIMDAL FM, SANDNES FM, SOGNEFJORD FM, TARBERT FM, BRENT GP. See also Norwegian Offshore Directorate bulletins.
    GARN FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    18.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    347.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3897.0
    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).
    3894.5
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    3.4
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    128
    Oldest penetrated age
    Age (according to Geologic Time Scale 2004 by F. M. Gradstein, et al. (2004)) of the oldest penetrated formation. May differ from age at TD for example in deviated wellbores. Examples of legal values: CRETACEOUS, EARLY CRETACEOUS, LATE JURASSIC, EARLY PERMIAN, EARLY TRIASSIC, EOCENE.
    EARLY JURASSIC
    Oldest penetrated formation
    Name of the oldest lithostratigraphic unit penetrated by the wellbore. Shown only for released wells. In most wellbores this is formation or group at total depth. May differ from formation or group at TD for example in wellbores drilled with high deviation or through faults. Examples of legal values: AMUNDSEN FM, BALDER FM, BASEMENT, BLODØKS FM, BRYNE FM, BURTON FM, COOK FM, DRAKE FM, DRAUPNE FM, EKOFISK FM, DUNLIN GP.
    ÅRE FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    65° 42' 59.1'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    7° 38' 18.83'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7289162.20
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    437524.41
    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.
    3756

  • Wellbore history
    General
    6507/5-2 was the third well drilled on the "A" fault block of the Skarv prospect. The well was planned as a down flank appraisal well of the 6507/5-1 Donnatello oil and gas discovery. The first well on the structure was the water wet 6507/6-2 well. The primary prospect lay in the Mid Jurassic sandstones of the Garn, Ile and Tilje Formations, with a secondary prospect in the Lower Cretaceous Lange sandstones. In the 6507/5-1 discovery well the Lange sandstones contained oil and the unit of interest was named the Gråsel prospect.
    Operations and results
    Appraisal well 6507/5-2 was spudded on 13 August 1999 with the semi-submersible installation "West Alpha" and drilled to TD at 3897 m in Early Jurassic Åre Formation sediments. The well was drilled with seawater and hi-vis pills down to 1050 m, with "BARASILC" water based silicate mud from 1050 m to 1964 m, with "Environmul" oil based mud from 1964 m to 3623 m, and with KCl / Polymer mud from 3623 m to TD. The Tertiary and upper Cretaceous consisted mostly of claystones. The Lower Cretaceous section was dominated by claystones with thin sandstone stringers. The thickest sandstone in this interval was the Gråsel Lange sandstone, some 9 m thick. The well penetrated the Gråsel prospect down flank of the 6507/5-1 discovery. The top Jurassic consisted of Spekk Formation source rock and underlying Melke claystones. These claystones act as a seal for the underlying middle Jurassic sandstones. The Garn Sandstone of the Jurassic contained a gas water contact at 3650.5 m confirming one of the pre drilling models for the well. Oil was seen in a sidewall core, and log analysis and HGINJ data suggested well 6507/5-2 was still in the oil column. Residual oil shows were seen down to 3681.5 m in the Not Formation. The Ile and Tilje sandstones were both in the water leg. Three cores were cut in the interval 3626 m to 3810 m in the Garn, Not, Ile, Ror, and Tilje Formations. Several MDT runs were made to obtain fluid samples. A sample from 2990 m in the Lange Formation turned out to contain mud. Gas and condensate were sampled at 3615.5 m, 3637 m, and 3647 m in the Garn Formation. Water was sampled at 3651.5 m (Garn), 3658 (Not), and 3850 m (Tilje). The well was permanently abandoned as a gas and condensate appraisal 23 September 1999.
    Testing
    No drill stem test was performed.

  • 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]
    1060.00
    3897.00

  • 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
    3626.0
    3684.8
    [m ]
    2
    3684.8
    3743.8
    [m ]
    3
    3743.8
    3812.3
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    186.3
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 3631-3636m
    Core photo at depth: 3636-3641m
    Core photo at depth: 3641-3646m
    Core photo at depth: 3646-3651m
    Core photo at depth: 3651-3656m
    3631-3636m
    3636-3641m
    3641-3646m
    3646-3651m
    3651-3656m
    Core photo at depth: 3656-3661m
    Core photo at depth: 3661-3666m
    Core photo at depth: 3666-3671m
    Core photo at depth: 3671-3676m
    Core photo at depth: 3676-3681m
    3656-3661m
    3661-3666m
    3666-3671m
    3671-3676m
    3676-3681m
    Core photo at depth: 3681-3685m
    Core photo at depth: 3685-3690m
    Core photo at depth: 3690-3695m
    Core photo at depth: 3695-3700m
    Core photo at depth: 3700-3705m
    3681-3685m
    3685-3690m
    3690-3695m
    3695-3700m
    3700-3705m
    Core photo at depth: 3705-3710m
    Core photo at depth: 3710-3715m
    Core photo at depth: 3715-3720m
    Core photo at depth: 3720-3725m
    Core photo at depth: 3725-3730m
    3705-3710m
    3710-3715m
    3715-3720m
    3720-3725m
    3725-3730m
    Core photo at depth: 3730-3735m
    Core photo at depth: 3735-3740m
    Core photo at depth: 3740-3744m
    Core photo at depth: 3744-3749m
    Core photo at depth: 3749-3754m
    3730-3735m
    3735-3740m
    3740-3744m
    3744-3749m
    3749-3754m
    Core photo at depth: 3754-3759m
    Core photo at depth: 3759-3764m
    Core photo at depth: 3764-3769m
    Core photo at depth: 3769-3774m
    Core photo at depth: 3774-3779m
    3754-3759m
    3759-3764m
    3764-3769m
    3769-3774m
    3774-3779m
    Core photo at depth: 3779-3784m
    Core photo at depth: 3784-3789m
    Core photo at depth: 3789-3794m
    Core photo at depth: 3794-3799m
    Core photo at depth: 3799-3804m
    3779-3784m
    3784-3789m
    3789-3794m
    3794-3799m
    3799-3804m
    Core photo at depth: 3804-3809m
    Core photo at depth: 3809-3811m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    3804-3809m
    3809-3811m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1060.0
    [m]
    DC
    RRI
    1090.0
    [m]
    DC
    RRI
    1120.0
    [m]
    DC
    RRI
    1150.0
    [m]
    DC
    RRI
    1180.0
    [m]
    DC
    RRI
    1210.0
    [m]
    DC
    RRI
    1240.0
    [m]
    DC
    RRI
    1270.0
    [m]
    DC
    RRI
    1300.0
    [m]
    DC
    RRI
    1330.0
    [m]
    DC
    RRI
    1360.0
    [m]
    DC
    RRI
    1390.0
    [m]
    DC
    RRI
    1430.0
    [m]
    DC
    RRI
    1460.0
    [m]
    DC
    RRI
    1490.0
    [m]
    DC
    RRI
    1520.0
    [m]
    DC
    RRI
    1550.0
    [m]
    DC
    RRI
    1580.0
    [m]
    DC
    RRI
    1610.0
    [m]
    DC
    RRI
    1640.0
    [m]
    DC
    RRI
    1670.0
    [m]
    DC
    RRI
    1700.0
    [m]
    DC
    RRI
    1730.0
    [m]
    DC
    RRI
    1760.0
    [m]
    DC
    RRI
    1800.0
    [m]
    DC
    RRI
    1830.0
    [m]
    DC
    RRI
    1860.0
    [m]
    DC
    RRI
    1890.0
    [m]
    DC
    RRI
    1920.0
    [m]
    DC
    RRI
    1940.0
    [m]
    DC
    RRI
    1960.0
    [m]
    DC
    RRI
    1980.0
    [m]
    DC
    RRI
    2000.0
    [m]
    DC
    RRI
    2020.0
    [m]
    DC
    RRI
    2040.0
    [m]
    DC
    RRI
    2060.0
    [m]
    DC
    RRI
    2080.0
    [m]
    DC
    RRI
    2100.0
    [m]
    DC
    RRI
    2120.0
    [m]
    DC
    RRI
    2140.0
    [m]
    DC
    RRI
    2160.0
    [m]
    DC
    RRI
    2180.0
    [m]
    DC
    RRI
    2200.0
    [m]
    DC
    RRI
    2220.0
    [m]
    DC
    RRI
    2240.0
    [m]
    DC
    RRI
    2260.0
    [m]
    DC
    RRI
    2280.0
    [m]
    DC
    RRI
    2300.0
    [m]
    DC
    RRI
    2320.0
    [m]
    DC
    RRI
    2340.0
    [m]
    DC
    RRI
    2360.0
    [m]
    DC
    RRI
    2380.0
    [m]
    DC
    RRI
    2400.0
    [m]
    DC
    RRI
    2420.0
    [m]
    DC
    RRI
    2429.0
    [m]
    DC
    RRI
    2440.0
    [m]
    DC
    RRI
    2460.0
    [m]
    DC
    RRI
    2480.0
    [m]
    DC
    RRI
    2500.0
    [m]
    DC
    RRI
    2520.0
    [m]
    DC
    RRI
    2540.0
    [m]
    DC
    RRI
    2560.0
    [m]
    DC
    RRI
    2580.0
    [m]
    DC
    RRI
    2600.0
    [m]
    DC
    RRI
    2616.0
    [m]
    DC
    RRI
    2634.0
    [m]
    DC
    RRI
    2649.0
    [m]
    DC
    RRI
    2661.0
    [m]
    DC
    RRI
    2676.0
    [m]
    DC
    RRI
    2694.0
    [m]
    DC
    RRI
    2706.0
    [m]
    DC
    RRI
    2710.5
    [m]
    SWC
    RRI
    2724.0
    [m]
    DC
    RRI
    2727.2
    [m]
    SWC
    RRI
    2736.0
    [m]
    DC
    RRI
    2752.0
    [m]
    DC
    RRI
    2766.0
    [m]
    DC
    RRI
    2784.0
    [m]
    DC
    RRI
    2796.0
    [m]
    DC
    RRI
    2814.0
    [m]
    DC
    RRI
    2826.0
    [m]
    DC
    RRI
    2833.5
    [m]
    SWC
    RRI
    2844.0
    [m]
    DC
    RRI
    2856.0
    [m]
    DC
    RRI
    2856.7
    [m]
    SWC
    RRI
    2864.0
    [m]
    SWC
    RRI
    2874.0
    [m]
    DC
    RRI
    2886.0
    [m]
    DC
    RRI
    2896.0
    [m]
    SWC
    RRI
    2904.0
    [m]
    DC
    RRI
    2916.0
    [m]
    DC
    RRI
    2932.0
    [m]
    DC
    RRI
    2950.0
    [m]
    DC
    RRI
    2951.5
    [m]
    SWC
    RRI
    2968.0
    [m]
    DC
    RRI
    2980.0
    [m]
    DC
    RRI
    2998.0
    [m]
    DC
    RRI
    3010.0
    [m]
    DC
    RRI
    3019.0
    [m]
    SWC
    RRI
    3028.0
    [m]
    DC
    RRI
    3029.0
    [m]
    SWC
    RRI
    3035.5
    [m]
    SWC
    RRI
    3044.0
    [m]
    SWC
    RRI
    3048.0
    [m]
    DC
    RRI
    3050.0
    [m]
    SWC
    RRI
    3061.0
    [m]
    SWC
    RRI
    3063.0
    [m]
    DC
    RRI
    3075.0
    [m]
    DC
    RRI
    3093.0
    [m]
    DC
    RRI
    3108.0
    [m]
    DC
    RRI
    3123.0
    [m]
    DC
    RRI
    3135.0
    [m]
    DC
    RRI
    3150.0
    [m]
    DC
    RRI
    3165.0
    [m]
    DC
    RRI
    3180.0
    [m]
    DC
    RRI
    3195.0
    [m]
    DC
    RRI
    3205.0
    [m]
    SWC
    RRI
    3210.0
    [m]
    DC
    RRI
    3234.0
    [m]
    DC
    RRI
    3249.0
    [m]
    DC
    RRI
    3264.0
    [m]
    DC
    RRI
    3279.0
    [m]
    DC
    RRI
    3294.0
    [m]
    DC
    RRI
    3309.0
    [m]
    DC
    RRI
    3324.0
    [m]
    DC
    RRI
    3339.0
    [m]
    DC
    RRI
    3354.0
    [m]
    DC
    RRI
    3369.0
    [m]
    DC
    RRI
    3384.0
    [m]
    DC
    RRI
    3399.0
    [m]
    DC
    RRI
    3417.0
    [m]
    DC
    RRI
    3429.0
    [m]
    DC
    RRI
    3444.0
    [m]
    DC
    RRI
    3459.0
    [m]
    DC
    RRI
    3474.0
    [m]
    DC
    RRI
    3489.0
    [m]
    DC
    RRI
    3510.0
    [m]
    DC
    RRI
    3519.0
    [m]
    DC
    RRI
    3528.0
    [m]
    DC
    RRI
    3537.0
    [m]
    DC
    RRI
    3546.0
    [m]
    DC
    RRI
    3555.0
    [m]
    DC
    RRI
    3564.0
    [m]
    DC
    RRI
    3573.0
    [m]
    DC
    RRI
    3577.8
    [m]
    SWC
    RRI
    3582.0
    [m]
    DC
    RRI
    3591.0
    [m]
    DC
    RRI
    3600.0
    [m]
    DC
    RRI
    3605.0
    [m]
    SWC
    RRI
    3609.0
    [m]
    DC
    RRI
    3618.0
    [m]
    DC
    RRI
    3635.6
    [m]
    C
    RRI
    3650.8
    [m]
    C
    RRI
    3655.7
    [m]
    C
    RRI
    3665.6
    [m]
    C
    RRI
    3672.8
    [m]
    C
    RRI
    3684.5
    [m]
    C
    RRI
    3693.6
    [m]
    C
    RRI
    3697.4
    [m]
    C
    RRI
    3701.8
    [m]
    C
    RRI
    3712.5
    [m]
    C
    RRI
    3719.5
    [m]
    C
    RRI
    3720.7
    [m]
    C
    RRI
    3726.8
    [m]
    C
    RRI
    3736.2
    [m]
    C
    RRI
    3747.8
    [m]
    C
    RRI
    3754.5
    [m]
    C
    RRI
    3765.3
    [m]
    C
    RRI
    3775.2
    [m]
    C
    RRI
    3776.6
    [m]
    C
    RRI
    3781.8
    [m]
    C
    RRI
    3791.8
    [m]
    C
    RRI
    3799.6
    [m]
    C
    RRI
    3809.0
    [m]
    C
    RRI
    3819.0
    [m]
    DC
    RRI
    3828.0
    [m]
    DC
    RRI
    3837.0
    [m]
    DC
    RRI
    3846.0
    [m]
    DC
    RRI
    3855.0
    [m]
    DC
    RRI
    3864.0
    [m]
    DC
    RRI

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.49

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    1.99
    pdf
    1.63
    pdf
    1.02

  • 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
    4.21
    .PDF
    83.39

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    ARI DSI MSFL EMS GPIT ACTS
    3600
    3901
    ARI DSI MSFL GPIT ACTS
    3550
    3897
    IPLT
    3565
    3890
    MDT
    2813
    3616
    MDT
    2813
    3864
    MSCT GR
    3044
    3618
    MWD - DIR RAB
    3730
    3897
    MWD - RAB
    3623
    3730
    MWD CDR - DIR
    454
    1050
    MWD CDR - DIR ISON
    1050
    1964
    MWD CDR - RAB
    1964
    3623
    PEX DSI AITB EMS GPIT ACTS
    1964
    3623
    VSP
    988
    3880

  • 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
    450.0
    36
    450.0
    0.00
    LOT
    SURF.COND.
    20
    1053.0
    26
    1054.0
    1.45
    LOT
    INTERM.
    13 3/8
    1968.0
    17 1/2
    1970.0
    1.81
    LOT
    INTERM.
    9 5/8
    3602.0
    12 1/4
    3603.0
    0.00
    LOT
    OPEN HOLE
    3897.0
    8 1/2
    3897.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    407
    1.08
    SEAWATER
    1050
    1.36
    31.0
    BARASILC
    1662
    1.39
    39.0
    BARASILC
    1914
    1.50
    45.0
    BARASILC
    1964
    1.50
    30.0
    BARASILC
    2518
    1.61
    23.0
    ENVIROMUL
    3142
    1.61
    29.0
    ENVIROMUL
    3329
    1.61
    28.0
    ENVIROMUL
    3623
    1.61
    28.0
    ENVIROMUL

  • Thin sections at the Norwegian Offshore Directorate
    Thin sections at the Norwegian Offshore Directorate
    Depth
    Unit
    4164.42
    [m ]
    4166.38
    [m ]
    0.00
    [m ]

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