Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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24.11.2024 - 01:27
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6608/10-11 S

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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.
    6608/10-11 S
    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
    Press release
    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.
    6608/10-11
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    ST0103 Inline 5526 & Crossline 1663
    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.
    Statoil ASA (old)
    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.
    1121-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.
    35
    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,
    12.07.2006
    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.
    15.08.2006
    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.
    15.08.2008
    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.
    18.12.2008
    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
    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.
    NOT FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    24.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    375.7
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3725.1
    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).
    3243.3
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    42.3
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    122
    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.
    TILJE FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    66° 0' 48.68'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    8° 3' 14.73'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7321926.37
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    457090.31
    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.
    5386

  • Wellbore history
    General
    Well 6608/10-11 S was drilled on the Norne field, located on the border betveene Dønnn Terasss and the Nordland Ridge in the south-western of block 6608/10.The primary objective for the exploration well 6608/10-11 S was to establish the existence of hydrocarbons in the Middle and Early Jurassic reservoir sandstones of the Fangst and Båt Group in the Trost prospect. The Trost prospect is located on a down-faulted fault block west of the Norne field. The stratigraphy is similar to the Norne reservoirs, and Not Formation sandstone is the main reservoir.
    Operations and results
    Well 6608/10-11 S was spudded with the semi-submersible installation Transocean Arctic on 12 July 2006 and drilled to TD at 3725 m (3243 m TVD) in the Tilje Formation. The well 6608/10-11 S was side tracked from Norne Well 6608/10-K-3 H, hence it was designed as a deviated well with kick off point from 6608/10-K-3 H below 13 3/8" casing shoe at 1366.1 m (1328.2 m TVD). The well was drilled with Carbo-Sea oil based mud from kick-off to TD.
    The observed stratigraphy from the kick off point and down to the Fangst Group was generally in accordance with the prognosis. The Melke Formation was approximately 33 m thicker than prognosed, and the biggest discrepancies were therefore found from top Not Formation to TD of the well, where the formation tops came in from 36 to 74 m TVD deeper than prognosed.
    Gas was proven in the Not Formation sandstone. This was indicated by both gamma ray and resistivity logs, and was confirmed by neutron and porosity logs, together with MDT pressure points. White to very pale yellow direct and slow cut fluorescence was observed in the reservoir section, but was probably largely due to oil based mud fluorescence and its invasion of the cuttings. Similar fluorescence was seen in the lower water zone of the reservoir.
    No cores were cut. MDT gas samples were taken at 3511.2 m (3055.5 m TVD).
    The well was permanently plugged back to 13 3/8" casing shoe and abandoned on 15 August 2006. It is classified as a gas discovery
    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]
    1380.00
    3724.00

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1380.0
    [m]
    DC
    MICROSTR
    1390.0
    [m]
    DC
    MICROS
    1400.0
    [m]
    DC
    MICROS
    1410.0
    [m]
    DC
    MICROS
    1420.0
    [m]
    DC
    MICROS
    1430.0
    [m]
    DC
    MICROS
    1440.0
    [m]
    DC
    MICROS
    1480.0
    [m]
    DC
    MICROS
    1490.0
    [m]
    DC
    MICROS
    1500.0
    [m]
    DC
    MICROS
    1520.0
    [m]
    DC
    MICROS
    1530.0
    [m]
    DC
    MICROS
    1540.0
    [m]
    DC
    MICROS
    1560.0
    [m]
    DC
    MICROS
    1570.0
    [m]
    DC
    MICROS
    1590.0
    [m]
    DC
    MICROS
    1600.0
    [m]
    DC
    MICROS
    1620.0
    [m]
    DC
    MICROS
    1630.0
    [m]
    DC
    MICROS
    1640.0
    [m]
    DC
    MICROS
    1650.0
    [m]
    DC
    MICROS
    1660.0
    [m]
    DC
    MICROS
    1670.0
    [m]
    DC
    MICROS
    1680.0
    [m]
    DC
    MICROS
    1700.0
    [m]
    DC
    MICROS
    1720.0
    [m]
    DC
    MICROS
    1740.0
    [m]
    DC
    MICROS
    1760.0
    [m]
    DC
    MICROS
    1780.0
    [m]
    DC
    MICROS
    1800.0
    [m]
    DC
    MICROS
    1820.0
    [m]
    DC
    MICROS
    1840.0
    [m]
    DC
    MICROS
    1860.0
    [m]
    DC
    MICROS
    1880.0
    [m]
    DC
    MICROS
    1900.0
    [m]
    DC
    MICROS
    1920.0
    [m]
    DC
    MICROS
    1940.0
    [m]
    DC
    MICROS
    1960.0
    [m]
    DC
    MICROS
    1980.0
    [m]
    DC
    MICROS
    2000.0
    [m]
    DC
    MICROS
    2020.0
    [m]
    DC
    MICROS
    2040.0
    [m]
    DC
    MICROS
    2060.0
    [m]
    DC
    MICROS
    2080.0
    [m]
    DC
    MICROS
    2100.0
    [m]
    DC
    MICROS
    2120.0
    [m]
    DC
    MICROS
    2140.0
    [m]
    DC
    MICROS
    2160.0
    [m]
    DC
    MICROS
    2180.0
    [m]
    DC
    MICROS
    2200.0
    [m]
    DC
    MICROS
    2220.0
    [m]
    DC
    MICROS
    2260.0
    [m]
    DC
    MICROS
    2280.0
    [m]
    DC
    MICROS
    2300.0
    [m]
    DC
    MICROS
    2320.0
    [m]
    DC
    MICROS
    2340.0
    [m]
    DC
    MICROS
    2360.0
    [m]
    DC
    MICROS
    2380.0
    [m]
    DC
    MICROS
    2400.0
    [m]
    DC
    MICROS
    2420.0
    [m]
    DC
    MICROS
    2440.0
    [m]
    DC
    MICROS
    2460.0
    [m]
    DC
    MICROS
    2480.0
    [m]
    DC
    MICROS
    2500.0
    [m]
    DC
    MICROS
    2520.0
    [m]
    DC
    MICROS
    2540.0
    [m]
    DC
    MICROS
    2560.0
    [m]
    DC
    MICROS
    2580.0
    [m]
    DC
    MICROS
    2600.0
    [m]
    DC
    MICROS
    2620.0
    [m]
    DC
    MICROS
    2640.0
    [m]
    DC
    MICROS
    2660.0
    [m]
    DC
    MICROS
    2680.0
    [m]
    DC
    MICROS
    2700.0
    [m]
    DC
    MICROS
    2740.0
    [m]
    DC
    MICROS
    2760.0
    [m]
    DC
    MICROS
    2780.0
    [m]
    DC
    MICROS
    2800.0
    [m]
    DC
    MICROS
    2820.0
    [m]
    DC
    MICROS
    2830.0
    [m]
    DC
    MICROS
    2840.0
    [m]
    DC
    MICROS
    2850.0
    [m]
    DC
    MICROS
    2854.0
    [m]
    DC
    MICROS
    2860.0
    [m]
    DC
    MICROS
    2866.0
    [m]
    DC
    MICROS
    2872.0
    [m]
    DC
    MICROS
    2878.0
    [m]
    DC
    MICROS
    2884.0
    [m]
    DC
    MICROS
    2890.0
    [m]
    DC
    MICROS
    2896.0
    [m]
    DC
    MICROS
    2902.0
    [m]
    DC
    MICROS
    2923.0
    [m]
    DC
    MICROS
    2929.0
    [m]
    DC
    MICROS
    2935.0
    [m]
    DC
    MICROS
    2941.0
    [m]
    DC
    MICROS
    2947.0
    [m]
    DC
    MICROS
    2953.0
    [m]
    DC
    MICROS
    2959.0
    [m]
    DC
    MICROS
    2965.0
    [m]
    DC
    MICROS
    2971.0
    [m]
    DC
    MICROS
    2977.0
    [m]
    DC
    MICROS
    2983.0
    [m]
    DC
    MICROS
    2992.0
    [m]
    DC
    MICROS
    3004.0
    [m]
    DC
    MICROS
    3016.0
    [m]
    DC
    MICROS
    3028.0
    [m]
    DC
    MICROS
    3040.0
    [m]
    DC
    MICROS
    3052.0
    [m]
    DC
    MICROS
    3064.0
    [m]
    DC
    MICROS
    3076.0
    [m]
    DC
    MICROS
    3082.0
    [m]
    DC
    MICROS
    3088.0
    [m]
    DC
    MICROS
    3093.0
    [m]
    DC
    MICROS
    3100.0
    [m]
    DC
    MICROS
    3106.0
    [m]
    DC
    MICROS
    3112.0
    [m]
    DC
    MICROS
    3118.0
    [m]
    DC
    MICROS
    3124.0
    [m]
    DC
    MICROS
    3130.0
    [m]
    DC
    MICROS
    3136.0
    [m]
    DC
    MICROS
    3148.0
    [m]
    DC
    MICROS
    3154.0
    [m]
    DC
    MICROS
    3160.0
    [m]
    DC
    MICROS
    3166.0
    [m]
    DC
    MICROS
    3172.0
    [m]
    DC
    MICROS
    3178.0
    [m]
    DC
    MICROS
    3184.0
    [m]
    DC
    MICROS
    3190.0
    [m]
    DC
    MICROS
    3196.0
    [m]
    DC
    MICROS
    3202.0
    [m]
    DC
    MICROS
    3208.0
    [m]
    DC
    MICROS
    3214.0
    [m]
    DC
    MICROS
    3220.0
    [m]
    DC
    MICROS
    3226.0
    [m]
    DC
    MICROS
    3232.0
    [m]
    DC
    MICROS
    3256.0
    [m]
    DC
    MICROS
    3262.0
    [m]
    DC
    MICROS
    3280.0
    [m]
    DC
    MICROS
    3286.0
    [m]
    DC
    MICROS
    3292.0
    [m]
    DC
    MICROS
    3298.0
    [m]
    DC
    MICROS
    3304.0
    [m]
    DC
    MICROS
    3310.0
    [m]
    DC
    MICROS
    3316.0
    [m]
    DC
    MICROS
    3322.0
    [m]
    DC
    MICROS
    3328.0
    [m]
    DC
    MICROS
    3334.0
    [m]
    DC
    MICROS
    3340.0
    [m]
    DC
    MICROS
    3346.0
    [m]
    DC
    MICROS
    3354.0
    [m]
    DC
    MICROS
    3364.0
    [m]
    DC
    MICROS
    3370.0
    [m]
    DC
    MICROS
    3376.0
    [m]
    DC
    MICROS
    3382.0
    [m]
    DC
    MICROS
    3388.0
    [m]
    DC
    MICROS
    3394.0
    [m]
    DC
    MICROS
    3397.0
    [m]
    DC
    MICROS
    3400.0
    [m]
    DC
    MICROS
    3403.0
    [m]
    DC
    MICROS
    3421.0
    [m]
    DC
    MICROS
    3424.0
    [m]
    DC
    MICROS
    3427.0
    [m]
    DC
    MICROS
    3430.0
    [m]
    DC
    MICROS
    3433.0
    [m]
    DC
    MICROS
    3436.0
    [m]
    DC
    MICROS
    3439.0
    [m]
    DC
    MICROS
    3442.0
    [m]
    DC
    MICROS
    3445.0
    [m]
    DC
    MICROS
    3448.0
    [m]
    DC
    MICROS
    3451.0
    [m]
    DC
    MICROS
    3454.0
    [m]
    DC
    MICROS
    3460.0
    [m]
    DC
    MICROS
    3463.0
    [m]
    DC
    MICROS
    3466.0
    [m]
    DC
    MICROS
    3469.0
    [m]
    DC
    MICROS
    3472.0
    [m]
    DC
    MICROS
    3475.0
    [m]
    DC
    MICROS
    3478.0
    [m]
    DC
    MICROS
    3481.0
    [m]
    DC
    MICROS
    3484.0
    [m]
    DC
    MICROS
    3487.0
    [m]
    DC
    MICROS
    3490.0
    [m]
    DC
    MICROS
    3493.0
    [m]
    DC
    MICROS
    3496.0
    [m]
    DC
    MICROS
    3499.0
    [m]
    DC
    MICROS
    3502.0
    [m]
    DC
    MICROS
    3505.0
    [m]
    DC
    MICROS
    3508.0
    [m]
    DC
    MICROS
    3511.0
    [m]
    DC
    MICROS
    3514.0
    [m]
    DC
    MICROS
    3517.0
    [m]
    DC
    MICROS
    3520.0
    [m]
    DC
    MICROS
    3523.0
    [m]
    DC
    MICROS
    3535.0
    [m]
    DC
    MICROS
    3538.0
    [m]
    DC
    MICROS
    3541.0
    [m]
    DC
    MICROS
    3544.0
    [m]
    DC
    MICROS
    3547.0
    [m]
    DC
    MICROS
    3550.0
    [m]
    DC
    MICROS
    3553.0
    [m]
    DC
    MICROS
    3556.0
    [m]
    DC
    MICROS
    3559.0
    [m]
    DC
    MICROS
    3562.0
    [m]
    DC
    MICROS
    3565.0
    [m]
    DC
    MICROS
    3568.0
    [m]
    DC
    MICROS
    3571.0
    [m]
    DC
    MICROS
    3574.0
    [m]
    DC
    MICROS
    3577.0
    [m]
    DC
    MICROS
    3580.0
    [m]
    DC
    MICROS
    3583.0
    [m]
    DC
    MICROS
    3586.0
    [m]
    DC
    MICROS
    3589.0
    [m]
    DC
    MICROS
    3592.0
    [m]
    DC
    MICROS
    3595.0
    [m]
    DC
    MICROS
    3598.0
    [m]
    DC
    MICROS
    3601.0
    [m]
    DC
    MICROS
    3604.0
    [m]
    DC
    MICROS
    3607.0
    [m]
    DC
    MICROS
    3610.0
    [m]
    DC
    MICROS
    3613.0
    [m]
    DC
    MICROS
    3619.0
    [m]
    DC
    MICROS
    3625.0
    [m]
    DC
    MICROS
    3628.0
    [m]
    DC
    MICROS
    3631.0
    [m]
    DC
    MICROS
    3634.0
    [m]
    DC
    MICROS
    3637.0
    [m]
    DC
    MICROS
    3640.0
    [m]
    DC
    MICROS
    3643.0
    [m]
    DC
    MICROS
    3646.0
    [m]
    DC
    MICROS
    3649.0
    [m]
    DC
    MICROS
    3652.0
    [m]
    DC
    MICROS
    3655.0
    [m]
    DC
    MICROS
    3658.0
    [m]
    DC
    MICROS
    3661.0
    [m]
    DC
    MICROS
    3664.0
    [m]
    DC
    MICROS
    3667.0
    [m]
    DC
    MICROS
    3670.0
    [m]
    DC
    MICROS
    3673.0
    [m]
    DC
    MICROS
    3676.0
    [m]
    DC
    MICROS
    3679.0
    [m]
    DC
    MICROS
    3682.0
    [m]
    DC
    MICROS
    3685.0
    [m]
    DC
    MICROS
    3688.0
    [m]
    DC
    MICROS
    3691.0
    [m]
    DC
    MICROS
    3694.0
    [m]
    DC
    MICROS
    3697.0
    [m]
    DC
    MICROS
    3700.0
    [m]
    DC
    MICROS
    3703.0
    [m]
    DC
    MICROS
    3706.0
    [m]
    DC
    MICROS
    3709.0
    [m]
    DC
    MICROS
    3712.0
    [m]
    DC
    MICROS
    3715.0
    [m]
    DC
    MICROS
    3718.0
    [m]
    DC
    MICROS
    3721.0
    [m]
    DC
    MICROS
    3724.0
    [m]
    DC
    MICROS

  • Lithostratigraphy

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    MDT DSI
    3393
    3720
    MDT DSI (MDT)
    3606
    3781
    MDT PRESSURE
    2903
    2948
    MDT SAMPLE
    3511
    0
    MWD - GR RES DIR
    1366
    3725
    PEX AIT
    3201
    3721
    PEX DSI
    2848
    3385
    VSP
    1200
    3385

  • 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
    INTERM.
    13 3/8
    1366.0
    17 1/2
    1371.0
    0.00
    LOT
    INTERM.
    9 5/8
    2845.0
    12 1/4
    2851.0
    1.50
    LOT
    LINER
    7
    3391.0
    8 1/2
    3392.0
    0.00
    LOT
    OPEN HOLE
    3725.0
    6
    3725.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    1877
    1.43
    46.0
    CARBO SEA
    2005
    1.43
    38.0
    CARBO SEA
    2915
    1.52
    34.0
    CARBO SEA
    2918
    1.52
    34.0
    CARBO SEA
    3392
    1.31
    22.0
    CARBO SEA
    3420
    1.30
    20.0
    CARBO SEA

  • 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