Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
25.11.2024 - 01:30
Time of last synchronization with Norwegian Offshore Directorate's internal systems

30/11-10

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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.
    30/11-10
    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.
    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.
    30/11-10
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    3D survey MC3D-NVG05 inline 1698 & xline 3057
    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 Petroleum AS
    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.
    1548-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.
    56
    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,
    01.11.2014
    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.
    26.12.2014
    Plugged date
    Date when plugging operations was finished, as reported by the operator to the Norwegian Offshore Directorate through DDRS (Daily Drilling Reporting System).
    26.12.2014
    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.
    26.12.2016
    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.
    26.12.2016
    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/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.
    TARBERT 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.
    NESS FM
    3rd level with HC, age
    Age of lithostratigraphic unit, 3rd level, where hydrocarbons were encountered. Examples of legal values: CRETACEOUS, EARLY CRETACEOUS, LATE JURASSIC, EOCENE.
    MIDDLE JURASSIC
    3rd level with HC, formation
    Name of lithostartigraphic unit, 3rd 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.
    ETIVE FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    23.5
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    104.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4079.0
    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).
    4078.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    2.9
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    140
    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.
    DRAKE FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    60° 14' 4.27'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 30' 37.16'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6677786.79
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    472879.26
    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.
    7595

  • Wellbore history
    General
    Well 30/11-10 was drilled on the Krafla North prospect located on the edge of the Horda Platform towards the Viking Graben. Krafla North is located north of and close to the 30/11-8 S Krafla discovery. The primary objective was to prove reserves in the Tarbert, Ness, and Etive formations of the Brent Group.
    Operations and results
    Wildcat well 30/11-10 was spudded with the semi-submersible installation Transocean Leader on 1 November 2014 and drilled to TD at 4079 m in the Early Jurassic Drake Formation. For field development data, acquisition purposes a 12 1/4'' pilot hole was drilled from below 20'' shoe and down through Skade, Oligocene and Grid sands to 1652 m. No significant problem was encountered in the operations. The well was drilled with spud mud down to 807 m and with XP-07 oil based mud from 807 m to TD.
    Top Brent Group, Tarbert Formation was encountered at 3445 m. The well proved oil in Tarbert and Etive Formations and rich gas-condensate in the Ness Formation. The upper part of Tarbert down to 3554 m had poor reservoir properties. The Brent Group succession proved oil-down-to (ODT) situations in most of the reservoir intervals. However, an in-well oil-water contact was estimated 3659 m in the Tarbert Formation based on PVT and pressure data. Shows were described throughout the Brent Group, including the Rannoch Formation. In the cored section of upper Drake Formation, weak residual shows were observed.
    Two cores were cut. Core number 1 recovered 54.5 meters from 3575 to 3629 m in the Tarbert Formation while core number 2 recovered 43.8 meters from 3997.2 m in the Rannoch Formation to 4041 m in the Drake Formation. MDT fluid samples were taken at 1025 m (water), 1313.5 m (water), 1463.5 (water), 3555.2 m (oil), 3590.3 m (oil), 3610.8 m (oil), 3663.8 m (water), 3896.7 m (oil), 3950.1 m (water), and 3994.2 m (oil).
    The well was permanently abandoned on 26 December 2014 as an oil and gas/condensate well.
    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]
    810.00
    4079.00

  • 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
    3575.0
    3629.5
    [m ]
    2
    3997.2
    4040.5
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    97.8
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    894.0
    [m]
    DC
    PETROSTR
    900.0
    [m]
    DC
    PETROS
    1023.0
    [m]
    DC
    PETROS
    1044.0
    [m]
    DC
    PETROS
    1068.0
    [m]
    DC
    PETROS
    1080.0
    [m]
    DC
    PETROS
    1095.0
    [m]
    DC
    PETROS
    1110.0
    [m]
    DC
    PETROS
    1125.0
    [m]
    DC
    PETROS
    1140.0
    [m]
    DC
    PETROS
    1155.0
    [m]
    DC
    PETROS
    1170.0
    [m]
    DC
    PETROS
    1185.0
    [m]
    DC
    PETROS
    1200.0
    [m]
    DC
    PETROS
    1215.0
    [m]
    DC
    PETROS
    1230.0
    [m]
    DC
    PETROS
    1245.0
    [m]
    DC
    PETROS
    1260.0
    [m]
    DC
    PETROS
    1275.0
    [m]
    DC
    PETROS
    1290.0
    [m]
    DC
    PETROS
    1305.0
    [m]
    DC
    PETROS
    1311.0
    [m]
    DC
    PETROS
    1365.0
    [m]
    DC
    PETROS
    1380.0
    [m]
    DC
    PETROS
    1395.0
    [m]
    DC
    PETROS
    1410.0
    [m]
    DC
    PETROS
    1426.0
    [m]
    DC
    PETROS
    1441.0
    [m]
    DC
    PETROS
    1456.0
    [m]
    DC
    PETROS
    1600.0
    [m]
    DC
    PETROS
    1630.0
    [m]
    DC
    PETROS
    1651.0
    [m]
    DC
    PETROS
    1680.0
    [m]
    DC
    PETROS
    1710.0
    [m]
    DC
    PETROS
    1740.0
    [m]
    DC
    PETROS
    1760.0
    [m]
    DC
    PETROS
    1840.0
    [m]
    DC
    PETROS
    1850.0
    [m]
    DC
    PETROS
    1880.0
    [m]
    DC
    PETROS
    1910.0
    [m]
    DC
    PETROS
    1940.0
    [m]
    DC
    PETROS
    1970.0
    [m]
    DC
    PETROS
    2000.0
    [m]
    DC
    PETROS
    2030.0
    [m]
    DC
    PETROS
    2060.0
    [m]
    DC
    PETROS
    2090.0
    [m]
    DC
    PETROS
    2120.0
    [m]
    DC
    PETROS
    2150.0
    [m]
    DC
    PETROS
    2180.0
    [m]
    DC
    PETROS
    2200.0
    [m]
    DC
    PETROS
    2220.0
    [m]
    DC
    PETROS
    2240.0
    [m]
    DC
    PETROS
    2260.0
    [m]
    DC
    PETROS
    2280.0
    [m]
    DC
    PETROS
    2300.0
    [m]
    DC
    PETROS
    2320.0
    [m]
    DC
    PETROS
    2340.0
    [m]
    DC
    PETROS
    2360.0
    [m]
    DC
    PETROS
    2380.0
    [m]
    DC
    PETROS
    2400.0
    [m]
    DC
    PETROS
    2420.0
    [m]
    DC
    PETROS
    2440.0
    [m]
    DC
    PETROS
    2460.0
    [m]
    DC
    PETROS
    2480.0
    [m]
    DC
    PETROS
    2500.0
    [m]
    DC
    PETROS
    2520.0
    [m]
    DC
    PETROS
    2610.0
    [m]
    DC
    PETROS
    2640.0
    [m]
    DC
    PETROS
    2670.0
    [m]
    DC
    PETROS
    2700.0
    [m]
    DC
    PETROS
    2730.0
    [m]
    DC
    PETROS
    2760.0
    [m]
    DC
    PETROS
    2790.0
    [m]
    DC
    PETROS
    2820.0
    [m]
    DC
    PETROS
    2850.0
    [m]
    DC
    PETROS
    2880.0
    [m]
    DC
    PETROS
    2910.0
    [m]
    DC
    PETROS
    2940.0
    [m]
    DC
    PETROS
    2970.0
    [m]
    DC
    PETROS
    3000.0
    [m]
    DC
    PETROS
    3030.0
    [m]
    DC
    PETROS
    3060.0
    [m]
    DC
    PETROS
    3090.0
    [m]
    DC
    PETROS
    3120.0
    [m]
    DC
    PETROS
    3150.0
    [m]
    DC
    PETROS
    3180.0
    [m]
    DC
    PETROS
    3210.0
    [m]
    DC
    PETROS
    3240.0
    [m]
    DC
    PETROS
    3380.0
    [m]
    DC
    PETROS
    3390.0
    [m]
    DC
    PETROS
    3400.0
    [m]
    DC
    PETROS
    3409.0
    [m]
    DC
    PETROS
    3417.0
    [m]
    DC
    PETROS
    3418.0
    [m]
    DC
    PETROS
    3436.0
    [m]
    DC
    PETROS
    3445.0
    [m]
    DC
    PETROS
    3454.0
    [m]
    DC
    PETROS
    3463.0
    [m]
    DC
    PETROS
    3472.0
    [m]
    DC
    PETROS
    3481.0
    [m]
    DC
    PETROS
    3490.0
    [m]
    DC
    PETROS
    3499.0
    [m]
    DC
    PETROS
    3508.0
    [m]
    DC
    PETROS
    3517.0
    [m]
    DC
    PETROS
    3526.0
    [m]
    DC
    PETROS
    3535.0
    [m]
    DC
    PETROS
    3544.0
    [m]
    DC
    PETROS
    3553.0
    [m]
    DC
    PETROS
    3562.0
    [m]
    DC
    PETROS
    3571.0
    [m]
    DC
    PETROS
    3575.0
    [m]
    C
    PETROS
    3581.3
    [m]
    C
    PETROS
    3585.0
    [m]
    C
    PETROS
    3590.4
    [m]
    C
    PETROS
    3595.6
    [m]
    C
    PETROS
    3597.3
    [m]
    C
    PETROS
    3605.0
    [m]
    C
    PETROS
    3619.1
    [m]
    C
    PETROS
    3619.8
    [m]
    C
    PETROS
    3620.2
    [m]
    C
    PETROS
    3621.7
    [m]
    C
    PETROS
    3623.4
    [m]
    C
    PETROS
    3628.5
    [m]
    C
    PETROS
    3634.0
    [m]
    DC
    PETROS
    3643.0
    [m]
    DC
    PETROS
    3652.0
    [m]
    DC
    PETROS
    3661.0
    [m]
    DC
    PETROS
    3670.0
    [m]
    DC
    PETROS
    3679.0
    [m]
    DC
    PETROS
    3688.0
    [m]
    DC
    PETROS
    3697.0
    [m]
    DC
    PETROS
    3706.0
    [m]
    DC
    PETROS
    3715.0
    [m]
    DC
    PETROS
    3724.0
    [m]
    DC
    PETROS
    3733.0
    [m]
    DC
    PETROS
    3742.0
    [m]
    DC
    PETROS
    3751.0
    [m]
    DC
    PETROS
    3760.0
    [m]
    DC
    PETROS
    3769.0
    [m]
    DC
    PETROS
    3778.0
    [m]
    DC
    PETROS
    3787.0
    [m]
    DC
    PETROS
    3796.0
    [m]
    DC
    PETROS
    3805.0
    [m]
    DC
    PETROS
    3814.0
    [m]
    DC
    PETROS
    3823.0
    [m]
    DC
    PETROS
    3832.0
    [m]
    DC
    PETROS
    3841.0
    [m]
    DC
    PETROS
    3850.0
    [m]
    DC
    PETROS
    3859.0
    [m]
    DC
    PETROS
    3868.0
    [m]
    DC
    PETROS
    3877.0
    [m]
    DC
    PETROS
    3886.0
    [m]
    DC
    PETROS
    3895.0
    [m]
    DC
    PETROS
    3904.0
    [m]
    DC
    PETROS
    3913.0
    [m]
    DC
    PETROS
    3922.0
    [m]
    DC
    PETROS
    3931.0
    [m]
    DC
    PETROS
    3940.0
    [m]
    DC
    PETROS
    3949.0
    [m]
    DC
    PETROS
    3958.0
    [m]
    DC
    PETROS
    3967.0
    [m]
    DC
    PETROS
    3976.0
    [m]
    DC
    PETROS
    3985.0
    [m]
    DC
    PETROS
    3994.0
    [m]
    DC
    PETROS
    3997.4
    [m]
    C
    PETROS
    4000.7
    [m]
    C
    PETROS
    4003.4
    [m]
    C
    PETROS
    4003.9
    [m]
    C
    PETROS
    4007.3
    [m]
    C
    PETROS
    4012.5
    [m]
    C
    PETROS
    4019.5
    [m]
    C
    PETROS
    4025.5
    [m]
    C
    PETROS
    4033.5
    [m]
    C
    PETROS
    4037.0
    [m]
    C
    PETROS
    4039.0
    [m]
    DC
    PETROS
    4048.0
    [m]
    DC
    PETROS
    4057.0
    [m]
    DC
    PETROS
    4066.0
    [m]
    DC
    PETROS
    4075.0
    [m]
    DC
    PETROS
    4079.0
    [m]
    DC
    PETROS

  • 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
    MINI
    3590.30
    0.00
    OIL
    YES
    MINI
    3610.70
    0.00
    OIL
    NO
    MINI
    3896.70
    0.00
    OIL
    YES
    MINI
    3994.20
    0.00
    OIL
    YES

  • Lithostratigraphy

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    AIT PEX HNGS
    3399
    4041
    AIT PPC MSIP PEX HNGS
    798
    1631
    CMR ECS GR
    3389
    4065
    MDT GR
    2100
    2291
    MDT GR
    3448
    4002
    MDT GR
    3555
    3994
    MDT GR
    3590
    3897
    MDT GR
    3663
    3897
    MSCT GR
    3447
    3897
    MSCT GR
    3652
    3997
    MSCT GR
    3654
    3995
    MSCT GR
    3997
    3999
    MWD - ARCVRES6 TELE
    3400
    4079
    MWD - ARCVRES9 TELE
    177
    2100
    MWD - PDX5 ARCVRES9 TELE
    2100
    3401
    MWD - TELE
    128
    183
    NGI PPC MSIP PPC GR
    3100
    4048
    PS PO LFA SC1 CMR GR
    798
    1631

  • 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
    178.4
    36
    184.0
    0.00
    SURF.COND.
    20
    798.2
    26
    807.0
    0.00
    810.0
    810.0
    1.35
    FIT
    PILOT HOLE
    1652.0
    12 1/4
    1652.0
    0.00
    INTERM.
    14
    2088.0
    17 1/2
    2103.0
    1.74
    LOT
    LINER
    9 5/8
    3399.5
    12 1/4
    3404.0
    1.90
    FIT
    OPEN HOLE
    4079.0
    8 1/2
    4079.0
    0.00

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    128
    1.35
    15.0
    Spud Mud
    138
    1.03
    27.0
    Spud Mud
    183
    1.35
    15.0
    Spud Mud
    324
    1.60
    20.0
    Kill Fluid- SW/Bentonite
    331
    1.03
    12.0
    Spud Mud
    588
    1.60
    20.0
    Kill Fluid- SW/Bentonite
    588
    1.03
    12.0
    Spud Mud
    588
    1.60
    20.0
    Kill Fluid- SW/Bentonite
    807
    1.22
    18.0
    OBM-Low ECD
    807
    1.35
    15.0
    Spud Mud
    810
    1.22
    19.0
    OBM-Low ECD
    1748
    1.22
    22.0
    OBM-Low ECD
    1998
    1.35
    20.0
    OBM-Low ECD
    2052
    1.22
    22.0
    OBM-Low ECD
    2200
    1.40
    26.0
    OBM-Low ECD
    2587
    1.33
    23.0
    OBM-Low ECD
    3152
    1.43
    25.0
    OBM-Low ECD
    3158
    1.82
    43.0
    OBM-Low ECD
    3213
    1.35
    21.0
    OBM-Low ECD
    3284
    1.83
    41.0
    OBM-Low ECD
    3331
    1.50
    29.0
    OBM-Low ECD
    3364
    1.83
    48.0
    OBM-Low ECD
    3401
    1.50
    29.0
    OBM-Low ECD
    3445
    1.83
    44.0
    OBM-Low ECD
    3546
    1.63
    35.0
    OBM-Low ECD
    3733
    1.70
    36.0
    OBM-Low ECD
    3997
    1.80
    38.0
    OBM-Low ECD
    4079
    1.83
    40.0
    OBM-Low ECD