Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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25.11.2024 - 01:30
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25/10-6 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.
    25/10-6 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
    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
    Well name
    Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    25/10-6
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    ST 9304- INLINE 648 & CROSSLINE 717
    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.
    836-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.
    88
    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,
    26.12.1995
    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.
    22.03.1996
    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.
    22.03.1998
    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.
    29.08.2003
    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.
    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.
    SHOWS
    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
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    23.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    117.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4706.0
    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).
    4281.5
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    43.5
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    158
    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.
    MIDDLE 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.
    SLEIPNER FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    59° 8' 8.69'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 1' 37.54'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6555724.91
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    444322.99
    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.
    2728

  • Wellbore history
    General
    Well 25/10-6 S is located West-Southwest of the Balder field. The main objectives for the well were to prove the hydrocarbon potentials of the Heimdal, Ty, and the Hugin Formations.
    Operations and results
    Wildcat well 25/10-6 S well was spudded with the semi-submersible installation "Deepsea Bergen" on 26 December 1995 and drilled deviated to a TD of 4706 m (4281.5 m TVD) in the Middle Jurassic Sleipner Formation. The well was drilled using bentonite / CMC EHV mud down to 1039 m, with "ANCO 2000" mud from 1039 m to 2377 m, and with oil based "ANCOVERT" mud from 2377 m to TD. Several drilling problems were encountered below 1339 m and it took 30 days more than budget to reach TD. The problems included mud pump failure, MWD failure and difficulties with controlling the angle, bad weather, and bit problems. Many of the problems were due to hard formation. The well was drilled vertically to 1631 m before building angle.
    Well 25/10-6 S drilled through sediments of Tertiary, Cretaceous and into Jurassic ages. The well penetrated the Heimdal Formation at 2317.5 m and the Ty Formation at 2636.5 m. The angle was then approximately 15.5°. The angle increased through the Shetland Group and reached a maximum of 43.5° at approximately 4330 m in the Vestland Group. The well penetrated the Hugin Formation at 4337.5 m (3995.5 m TVD), 41.5 m deeper than prognosed (at an angle of 42°). The potential reservoirs in Palaeocene sandstones (Heimdal and Ty Formations) were water bearing. The Hugin Formation contained hydrocarbons, but the core data and FMT-results showed tight formation. Three cores were cut in the Hugin Formation. Of these, a total of only 12.7 m core were recovered because a very hard formation wore out the bit earlier than expected No fluid samples were collected. The well was permanently plugged and abandoned on 22 March 1996 as a dry well with shows.
    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]
    1040.00
    4704.00

  • 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
    4339.2
    4343.5
    [m ]
    2
    4344.0
    4349.5
    [m ]
    3
    4397.0
    4399.7
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    12.5
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 4339-4343m
    Core photo at depth: 4344-4349m
    Core photo at depth: 4349-4399m
    Core photo at depth:  
    Core photo at depth:  
    4339-4343m
    4344-4349m
    4349-4399m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1040.0
    [m]
    DC
    RRI
    1060.0
    [m]
    DC
    RRI
    1070.0
    [m]
    DC
    RRI
    1090.0
    [m]
    DC
    RRI
    1100.0
    [m]
    DC
    RRI
    1120.0
    [m]
    DC
    RRI
    1130.0
    [m]
    DC
    RRI
    1150.0
    [m]
    DC
    RRI
    1170.0
    [m]
    DC
    RRI
    1190.0
    [m]
    DC
    RRI
    1200.0
    [m]
    DC
    RRI
    1220.0
    [m]
    DC
    RRI
    1240.0
    [m]
    DC
    RRI
    1260.0
    [m]
    DC
    RRI
    1270.0
    [m]
    DC
    RRI
    1290.0
    [m]
    DC
    RRI
    1300.0
    [m]
    DC
    RRI
    1320.0
    [m]
    DC
    RRI
    1330.0
    [m]
    DC
    RRI
    1350.0
    [m]
    DC
    RRI
    1370.0
    [m]
    DC
    RRI
    1390.0
    [m]
    DC
    RRI
    1400.0
    [m]
    DC
    RRI
    1420.0
    [m]
    DC
    RRI
    1430.0
    [m]
    DC
    RRI
    1450.0
    [m]
    DC
    RRI
    1470.0
    [m]
    DC
    RRI
    1480.0
    [m]
    DC
    RRI
    1500.0
    [m]
    DC
    RRI
    1510.0
    [m]
    DC
    RRI
    1530.0
    [m]
    DC
    RRI
    1540.0
    [m]
    DC
    RRI
    1570.0
    [m]
    DC
    RRI
    1590.0
    [m]
    DC
    RRI
    1600.0
    [m]
    DC
    RRI
    1620.0
    [m]
    DC
    RRI
    1630.0
    [m]
    DC
    RRI
    1650.0
    [m]
    DC
    RRI
    1660.0
    [m]
    DC
    RRI
    1680.0
    [m]
    DC
    RRI
    1700.0
    [m]
    DC
    RRI
    1710.0
    [m]
    DC
    RRI
    1730.0
    [m]
    DC
    RRI
    1740.0
    [m]
    DC
    RRI
    1760.0
    [m]
    DC
    RRI
    1770.0
    [m]
    DC
    RRI
    1790.0
    [m]
    DC
    RRI
    1800.0
    [m]
    DC
    RRI
    1820.0
    [m]
    DC
    RRI
    1830.0
    [m]
    DC
    RRI
    1850.0
    [m]
    DC
    RRI
    1860.0
    [m]
    DC
    RRI
    1880.0
    [m]
    DC
    RRI
    1890.0
    [m]
    DC
    RRI
    1910.0
    [m]
    DC
    RRI
    1930.0
    [m]
    DC
    RRI
    1940.0
    [m]
    DC
    RRI
    1960.0
    [m]
    DC
    RRI
    1970.0
    [m]
    DC
    RRI
    1990.0
    [m]
    DC
    RRI
    2000.0
    [m]
    DC
    RRI
    2020.0
    [m]
    DC
    RRI
    2030.0
    [m]
    DC
    RRI
    2050.0
    [m]
    DC
    RRI
    2060.0
    [m]
    DC
    RRI
    2080.0
    [m]
    DC
    RRI
    2100.0
    [m]
    DC
    RRI
    2110.0
    [m]
    DC
    RRI
    2120.0
    [m]
    DC
    RRI
    2130.0
    [m]
    DC
    RRI
    2140.0
    [m]
    DC
    RRI
    2150.0
    [m]
    DC
    RRI
    2160.0
    [m]
    DC
    RRI
    2170.0
    [m]
    DC
    RRI
    2180.0
    [m]
    DC
    RRI
    2190.0
    [m]
    DC
    RRI
    2200.0
    [m]
    DC
    RRI
    2210.0
    [m]
    DC
    RRI
    2220.0
    [m]
    DC
    RRI
    2229.0
    [m]
    DC
    RRI
    2232.6
    [m]
    SWC
    WESTLAB
    2238.0
    [m]
    DC
    RRI
    2247.0
    [m]
    DC
    RRI
    2256.0
    [m]
    DC
    RRI
    2265.0
    [m]
    DC
    RRI
    2272.6
    [m]
    SWC
    WESTLAB
    2283.0
    [m]
    DC
    RRI
    2287.6
    [m]
    SWC
    WESTLAB
    2292.0
    [m]
    DC
    RRI
    2301.0
    [m]
    DC
    RRI
    2307.6
    [m]
    SWC
    WESTLAB
    2328.0
    [m]
    DC
    RRI
    2337.0
    [m]
    DC
    RRI
    2346.0
    [m]
    DC
    RRI
    2355.0
    [m]
    DC
    RRI
    2364.0
    [m]
    DC
    RRI
    2373.0
    [m]
    DC
    RRI
    2385.0
    [m]
    DC
    RRI
    2406.0
    [m]
    DC
    RRI
    2418.0
    [m]
    DC
    RRI
    2427.0
    [m]
    DC
    RRI
    2436.0
    [m]
    DC
    RRI
    2448.0
    [m]
    DC
    RRI
    2457.0
    [m]
    DC
    RRI
    2469.0
    [m]
    DC
    RRI
    2478.0
    [m]
    DC
    RRI
    2490.0
    [m]
    DC
    RRI
    2499.0
    [m]
    DC
    RRI
    2508.0
    [m]
    DC
    RRI
    2526.0
    [m]
    DC
    RRI
    2535.0
    [m]
    DC
    RRI
    2553.0
    [m]
    DC
    RRI
    2580.0
    [m]
    DC
    RRI
    2589.0
    [m]
    DC
    RRI
    2598.0
    [m]
    DC
    RRI
    2616.0
    [m]
    DC
    RRI
    2631.1
    [m]
    SWC
    WESTLAB
    2637.5
    [m]
    SWC
    WESTLA
    2643.0
    [m]
    DC
    RRI
    2652.0
    [m]
    DC
    RRI
    2670.0
    [m]
    DC
    RRI
    2679.0
    [m]
    DC
    RRI
    2691.0
    [m]
    SWC
    WESTLAB
    2700.0
    [m]
    DC
    RRI
    2718.0
    [m]
    DC
    RRI
    3350.0
    [m]
    DC
    RRI
    3360.0
    [m]
    DC
    RRI
    3380.0
    [m]
    DC
    RRI
    3390.0
    [m]
    DC
    RRI
    3590.0
    [m]
    DC
    RRI
    3860.0
    [m]
    DC
    RRI
    3870.0
    [m]
    DC
    RRI
    3890.0
    [m]
    DC
    RRI
    3900.0
    [m]
    DC
    RRI
    3920.0
    [m]
    DC
    RRI
    3930.0
    [m]
    DC
    RRI
    3950.0
    [m]
    DC
    RRI
    3960.0
    [m]
    DC
    RRI
    3980.0
    [m]
    DC
    RRI
    3990.0
    [m]
    DC
    RRI
    4010.0
    [m]
    DC
    RRI
    4020.0
    [m]
    DC
    RRI
    4040.0
    [m]
    DC
    RRI
    4050.0
    [m]
    DC
    RRI
    4065.0
    [m]
    DC
    RRI
    4080.0
    [m]
    DC
    RRI
    4095.0
    [m]
    DC
    RRI
    4110.0
    [m]
    DC
    RRI
    4125.0
    [m]
    DC
    RRI
    4140.0
    [m]
    DC
    RRI
    4152.0
    [m]
    DC
    RRI
    4167.0
    [m]
    DC
    RRI
    4182.0
    [m]
    DC
    RRI
    4197.0
    [m]
    DC
    RRI
    4206.0
    [m]
    DC
    RRI
    4215.0
    [m]
    DC
    RRI
    4224.0
    [m]
    DC
    RRI
    4233.0
    [m]
    DC
    RRI
    4242.0
    [m]
    DC
    RRI
    4251.0
    [m]
    DC
    RRI
    4260.0
    [m]
    DC
    RRI
    4269.0
    [m]
    DC
    RRI
    4278.0
    [m]
    DC
    RRI
    4287.0
    [m]
    DC
    RRI
    4296.0
    [m]
    DC
    RRI
    4305.0
    [m]
    DC
    RRI
    4314.0
    [m]
    DC
    RRI
    4323.0
    [m]
    DC
    RRI
    4332.0
    [m]
    DC
    RRI
    4332.0
    [m]
    DC
    APT
    4335.0
    [m]
    DC
    APT
    4338.0
    [m]
    DC
    APT
    4338.0
    [m]
    DC
    RRI
    4339.2
    [m]
    C
    RRI
    4342.7
    [m]
    C
    RRI
    4343.2
    [m]
    C
    WESTLAB
    4344.7
    [m]
    C
    WESTLA
    4345.6
    [m]
    C
    APT
    4349.2
    [m]
    C
    APT
    4349.4
    [m]
    C
    WESTLAB
    4397.1
    [m]
    C
    APT
    4397.5
    [m]
    C
    WESTLAB
    4397.9
    [m]
    C
    APT
    4398.3
    [m]
    C
    WESTLAB
    4398.5
    [m]
    C
    APT
    4399.4
    [m]
    C
    APT
    4401.0
    [m]
    DC
    APT
    4413.0
    [m]
    DC
    APT
    4413.0
    [m]
    DC
    RRI
    4416.0
    [m]
    DC
    APT
    4419.0
    [m]
    DC
    APT
    4422.0
    [m]
    DC
    RRI
    4431.0
    [m]
    DC
    RRI
    4440.0
    [m]
    DC
    RRI
    4455.0
    [m]
    DC
    RRI
    4464.0
    [m]
    DC
    RRI
    4473.0
    [m]
    DC
    RRI
    4482.0
    [m]
    DC
    RRI
    4491.0
    [m]
    DC
    RRI
    4500.0
    [m]
    DC
    RRI
    4509.0
    [m]
    DC
    RRI
    4518.0
    [m]
    DC
    RRI
    4527.0
    [m]
    DC
    RRI
    4536.0
    [m]
    DC
    RRI
    4545.0
    [m]
    DC
    RRI
    4554.0
    [m]
    DC
    RRI
    4563.0
    [m]
    DC
    RRI
    4572.0
    [m]
    DC
    RRI
    4581.0
    [m]
    DC
    RRI
    4590.0
    [m]
    DC
    RRI
    4599.0
    [m]
    DC
    RRI
    4608.0
    [m]
    DC
    RRI
    4617.0
    [m]
    DC
    RRI
    4626.0
    [m]
    DC
    RRI
    4635.0
    [m]
    DC
    RRI
    4644.0
    [m]
    DC
    RRI
    4653.0
    [m]
    DC
    RRI
    4662.0
    [m]
    DC
    RRI
    4671.0
    [m]
    DC
    RRI
    4680.0
    [m]
    DC
    RRI
    4689.0
    [m]
    DC
    RRI
    4698.0
    [m]
    DC
    RRI
    4704.0
    [m]
    DC
    RRI

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.71

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    1.73
    pdf
    1.75

  • 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
    15.63

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CDL CN GR CHT
    4036
    4628
    DIPL MAC ZDL CN DSL
    2095
    3080
    DLL MAC ZDL GR
    1024
    2115
    DPIL MAC DSL CHT
    4038
    4637
    FMT GR
    2318
    2638
    FMT GR
    2318
    2735
    FMT GR CHT
    4361
    4690
    FMT QDYNE GR CHT
    0
    0
    FMT QDYNE GR CHT
    0
    0
    FMT QDYNE GR CHT
    0
    0
    MAC DSL
    2906
    4054
    MWD - DPR TF4
    204
    2375
    MWD - DPR TF4
    2483
    3014
    MWD - DPR TF5A
    3014
    3452
    MWD - NAVIGATOR
    2375
    2547
    SWC GR
    2232
    2760
    VSP GR
    1400
    4040
    VSP GR
    3890
    4180
    VSP GR
    4390
    4700

  • 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
    SURF.COND.
    30
    200.0
    36
    200.0
    0.00
    LOT
    INTERM.
    20
    1024.0
    26
    1026.0
    1.74
    LOT
    INTERM.
    13 3/8
    2210.0
    17 1/2
    2212.0
    1.79
    LOT
    INTERM.
    9 5/8
    4037.0
    12 1/4
    4037.0
    2.10
    LOT
    OPEN HOLE
    4706.0
    8 1/2
    4706.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    1024
    1.47
    21.0
    ANCO 2000
    1024
    1.47
    21.0
    ANCO 2000
    1562
    1.41
    18.0
    ANCO 2000
    1700
    1.47
    20.0
    ANCO 2000
    1860
    1.47
    20.0
    ANCO 2000
    2085
    1.47
    21.0
    ANCO 2000
    2216
    1.47
    21.0
    ANCO 2000
    2217
    1.47
    22.0
    ANCO 2000
    2250
    1.47
    19.0
    ANCO 2000
    2668
    1.30
    36.0
    ANCO VERT
    2719
    1.33
    40.0
    ANCO VERT
    2791
    1.35
    44.0
    ANCO VERT
    2859
    1.36
    34.0
    ANCO VERT
    2870
    1.36
    34.0
    ANCO VERT
    2982
    1.37
    31.0
    ANCO VERT
    3034
    1.37
    32.0
    ANCO VERT
    3132
    1.38
    34.0
    ANCO VERT
    3154
    1.38
    35.0
    ANCO VERT
    3303
    1.37
    37.0
    ANCO VERT
    3371
    1.38
    34.0
    ANCO VERT
    3458
    1.38
    36.0
    ANCO VERT
    3481
    1.38
    36.0
    ANCO VERT
    3614
    1.38
    35.0
    ANCO VERT
    3650
    1.38
    33.0
    ANCO VERT
    3782
    1.41
    35.0
    ANCO VERT
    3827
    1.41
    34.0
    ANCO VERT
    4049
    1.85
    43.0
    ANCO VERT
    4052
    1.85
    48.0
    ANCO VERT
    4208
    1.91
    47.0
    ANCO VERT
    4320
    1.95
    54.0
    ANCO VERT
    4337
    1.95
    50.0
    ANCO VERT
    4339
    1.95
    48.0
    ANCO VERT
    4350
    1.95
    46.0
    ANCO VERT
    4360
    1.95
    46.0
    ANCO VERT
    4403
    1.95
    49.0
    ANCO VERT
    4424
    1.95
    48.0
    ANCO VERT
    4430
    1.95
    48.0
    ANCO VERT
    4480
    1.95
    49.0
    ANCO VERT
    4514
    1.95
    48.0
    ANCO VERT
    4548
    1.95
    46.0
    ANCO VERT
    4611
    1.95
    46.0
    ANCO VERT
    4662
    1.95
    45.0
    ANCO VERT
    4702
    1.95
    47.0
    ANCO VERT
    4706
    1.95
    47.0
    ANCO VERT

  • 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
    0.21