Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
21.11.2024 - 01:28
Time of last synchronization with Norwegian Offshore Directorate's internal systems

6407/1-4

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.
    6407/1-4
    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.
    6407/1-4
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    ST 9503-INLINE 554 & CROSSLINE 1562
    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.
    846-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.
    77
    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,
    08.06.1996
    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.
    23.08.1996
    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.
    23.08.1998
    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.
    13.12.2005
    Purpose - planned
    Pre-drill purpose of the wellbore. Legal values for exploration wellbores: WILDCAT, APPRAISAL, WILDCAT-CCS, APPRAISAL-CCS. Example of legal values for development wellbores: OBSERVATION, PRODUCTION, INJECTION.
    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.
    OIL/GAS
    Discovery wellbore
    Indicator which tells if the wellbore made a new discovery. Legal values: YES, NO. Prior to press-release or other information regarding drilling results, the indicator will be “NO” as a default.
    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.
    25.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    286.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3805.0
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    141
    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.
    NOT FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    64° 51' 46.05'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    7° 1' 21.25'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7194806.98
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    406280.05
    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.
    2796

  • Wellbore history
    General
    Well 6407/1-4 was drilled primarily to appraise the 6407/1-3 Tyrihans Nord Discovery. The specific target was to encounter a free oil-water-contact in the Garn Formation. Secondary objective was to gather information from the possibly oil bearing Campanian sandstone interval (Nise Formation).
    Operations and results
    Appraisal well 6407/1-4 was spudded with the semi-submersible installation Byford Dolphin on 6 June 1996 and drilled to TD at 3805 m in the Middle Jurassic Not Formation. Due to a labour conflict the MWD services was not run in the top hole down to 810 m. In addition 183 hrs rig time was lost during the strike. The well was drilled with seawater and prehydrated bentonite sweeps down to 816 m, from 816 m to 1810 m with ANCO 2000 mud, and with oil based Ancovert mud from 1810 m to TD.
    The upper part of the Nise Formation was dominated by siltstone with abundant thin laminas of very fine sandstone and rare limestone stringers. From 2560 m the siltstone progressively grades to claystone, becoming 100 % claystone at 2620 m. Top Garn reservoir came in 101 m thick at 3675 m, 18 m deep to prognosis, so rock-volume above proven OWC was reduced. The reservoir was more cemented than expected. Trace fluorescence and crush cut was recorded in a single siltstone cutting sample from the Springar Formation at 2470 m, otherwise no shows were seen above the shales and claystones of the Late Jurassic Spekk and Melke Formations. Gas on oil on water was encountered in the Garn Formation reservoir. The gas/oil contact was at 3681 m, while the oil/water contact was at 3705 m. No shows were recorded below the OWC. One conventional core was cut from 2498 m to 2526 m in the Nise Formation. Two conventional cores were cut across both fluid contacts from 3679.0 m to 3740.0 m in the Garn Formation, A FMT water sample was taken below the OWC at 3709 m. Two segregated FMT samples were taken to collect gas (3679.2 m) and oil (3691.2 m).
    The well was permanently abandoned on 23 August 1996 as an oil and gas appraisal well.
    Testing
    One drill stem test was performed from 3687 m to 3693 m in the oil zone in the Garn Formation. The test produced at the end of the multirate period 29505 Sm3 gas and 243.9 Sm3 oil /day. The GOR was 120 Sm3/Sm3 and the oil density was 0.86 g/cm3.

  • 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]
    830.00
    3805.00

  • 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
    2498.0
    2526.0
    [m ]
    2
    3679.0
    3706.6
    [m ]
    3
    3706.6
    3739.0
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    88.0
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 2498-2502m
    Core photo at depth: 2502-2506m
    Core photo at depth: 2506-2510m
    Core photo at depth: 2510-2514m
    Core photo at depth: 2514-2518m
    2498-2502m
    2502-2506m
    2506-2510m
    2510-2514m
    2514-2518m
    Core photo at depth: 2518-2522m
    Core photo at depth: 2522-2526m
    Core photo at depth: 3679-3684m
    Core photo at depth: 3684-3689m
    Core photo at depth: 3689-3694m
    2518-2522m
    2522-2526m
    3679-3684m
    3684-3689m
    3689-3694m
    Core photo at depth: 3694-3699m
    Core photo at depth: 3699-3704m
    Core photo at depth: 3704-3706m
    Core photo at depth: 3706-3711m
    Core photo at depth: 3711-3716m
    3694-3699m
    3699-3704m
    3704-3706m
    3706-3711m
    3711-3716m
    Core photo at depth: 3716-3721m
    Core photo at depth: 3721-3726m
    Core photo at depth: 3726-3731m
    Core photo at depth: 3731-3736m
    Core photo at depth: 3736-3739m
    3716-3721m
    3721-3726m
    3726-3731m
    3731-3736m
    3736-3739m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1860.0
    [m]
    DC
    RRI
    1870.0
    [m]
    DC
    RRI
    1890.0
    [m]
    DC
    RRI
    1900.0
    [m]
    DC
    RRI
    1920.0
    [m]
    DC
    RRI
    1930.0
    [m]
    DC
    RRI
    1950.0
    [m]
    DC
    RRI
    1960.0
    [m]
    DC
    RRI
    1980.0
    [m]
    DC
    RRI
    1990.0
    [m]
    DC
    RRI
    2010.0
    [m]
    DC
    RRI
    2020.0
    [m]
    DC
    RRI
    2040.0
    [m]
    DC
    RRI
    2050.0
    [m]
    DC
    RRI
    2070.0
    [m]
    DC
    RRI
    2080.0
    [m]
    DC
    RRI
    2100.0
    [m]
    DC
    RRI
    2110.0
    [m]
    DC
    RRI
    2130.0
    [m]
    DC
    RRI
    2140.0
    [m]
    DC
    RRI
    2160.0
    [m]
    DC
    RRI
    2170.0
    [m]
    DC
    RRI
    2190.0
    [m]
    DC
    RRI
    2200.0
    [m]
    DC
    RRI
    2220.0
    [m]
    DC
    RRI
    2230.0
    [m]
    DC
    RRI
    2250.0
    [m]
    DC
    RRI
    2260.0
    [m]
    DC
    RRI
    2280.0
    [m]
    DC
    RRI
    2290.0
    [m]
    DC
    RRI
    2310.0
    [m]
    DC
    RRI
    2320.0
    [m]
    DC
    RRI
    2340.0
    [m]
    DC
    RRI
    2350.0
    [m]
    DC
    RRI
    2370.0
    [m]
    DC
    RRI
    2380.0
    [m]
    DC
    RRI
    2400.0
    [m]
    DC
    RRI
    2410.0
    [m]
    DC
    RRI
    2430.0
    [m]
    DC
    RRI
    2440.0
    [m]
    DC
    RRI
    2460.0
    [m]
    DC
    RRI
    2461.0
    [m]
    SWC
    WESTL
    2470.0
    [m]
    DC
    RRI
    2470.5
    [m]
    SWC
    WESTL
    2490.0
    [m]
    DC
    RRI
    2498.2
    [m]
    DC
    WESTL
    2503.7
    [m]
    C
    WESTL
    2508.8
    [m]
    C
    WESTL
    2513.8
    [m]
    C
    WESTL
    2519.7
    [m]
    C
    WESTL
    2525.8
    [m]
    C
    WESTL
    2539.0
    [m]
    SWC
    WESTL
    2540.0
    [m]
    DC
    RRI
    2550.0
    [m]
    DC
    RRI
    2570.0
    [m]
    DC
    RRI
    2580.0
    [m]
    DC
    RRI
    2600.0
    [m]
    DC
    RRI
    2610.0
    [m]
    DC
    RRI
    2630.0
    [m]
    DC
    RRI
    2640.0
    [m]
    DC
    RRI
    2660.0
    [m]
    DC
    RRI
    2670.0
    [m]
    DC
    RRI
    2690.0
    [m]
    DC
    RRI
    2700.0
    [m]
    DC
    RRI
    2720.0
    [m]
    SWC
    WESTL
    2720.0
    [m]
    DC
    RRI
    2730.0
    [m]
    DC
    RRI
    2750.0
    [m]
    DC
    RRI
    2760.0
    [m]
    DC
    RRI
    2780.0
    [m]
    DC
    RRI
    2800.0
    [m]
    DC
    RRI
    2820.0
    [m]
    DC
    RRI
    2830.0
    [m]
    DC
    RRI
    2850.0
    [m]
    DC
    RRI
    2860.0
    [m]
    DC
    RRI
    2880.0
    [m]
    DC
    RRI
    2890.0
    [m]
    DC
    RRI
    2910.0
    [m]
    DC
    RRI
    2920.0
    [m]
    DC
    RRI
    2940.0
    [m]
    DC
    RRI
    2948.0
    [m]
    SWC
    WESTL
    2950.0
    [m]
    DC
    RRI
    2970.0
    [m]
    DC
    RRI
    3120.0
    [m]
    DC
    RRI
    3122.5
    [m]
    SWC
    WESTL
    3135.0
    [m]
    SWC
    WESTL
    3140.0
    [m]
    DC
    RRI
    3150.0
    [m]
    DC
    RRI
    3160.0
    [m]
    SWC
    WESTL
    3170.0
    [m]
    DC
    RRI
    3180.0
    [m]
    DC
    RRI
    3186.0
    [m]
    SWC
    WESTL
    3200.0
    [m]
    DC
    RRI
    3210.0
    [m]
    DC
    RRI
    3230.0
    [m]
    DC
    RRI
    3240.0
    [m]
    DC
    RRI
    3260.0
    [m]
    DC
    RRI
    3270.0
    [m]
    DC
    RRI
    3290.0
    [m]
    DC
    RRI
    3300.0
    [m]
    DC
    RRI
    3317.0
    [m]
    SWC
    WESTL
    3320.0
    [m]
    DC
    RRI
    3330.0
    [m]
    DC
    RRI
    3350.0
    [m]
    DC
    RRI
    3356.0
    [m]
    SWC
    WESTL
    3356.0
    [m]
    SWC
    RRI
    3360.0
    [m]
    DC
    RRI
    3380.0
    [m]
    DC
    RRI
    3390.0
    [m]
    DC
    RRI
    3406.5
    [m]
    SWC
    WESTL
    3410.0
    [m]
    SWC
    WESTL
    3410.0
    [m]
    DC
    RRI
    3420.0
    [m]
    DC
    RRI
    3440.0
    [m]
    DC
    RRI
    3450.0
    [m]
    DC
    RRI
    3452.0
    [m]
    SWC
    WESTL
    3470.0
    [m]
    DC
    RRI
    3480.0
    [m]
    DC
    RRI
    3482.5
    [m]
    SWC
    WESTL
    3492.5
    [m]
    SWC
    WESTL
    3500.0
    [m]
    DC
    RRI
    3531.0
    [m]
    DC
    RRI
    3540.0
    [m]
    DC
    RRI
    3546.0
    [m]
    DC
    RRI
    3549.5
    [m]
    SWC
    WESTL
    3552.0
    [m]
    DC
    RRI
    3558.0
    [m]
    DC
    RRI
    3564.0
    [m]
    DC
    RRI
    3576.0
    [m]
    DC
    RRI
    3582.0
    [m]
    SWC
    WESTL
    3582.0
    [m]
    DC
    RRI
    3587.0
    [m]
    SWC
    WESTL
    3588.0
    [m]
    DC
    RRI
    3594.0
    [m]
    DC
    RRI
    3600.0
    [m]
    DC
    RRI
    3604.0
    [m]
    SWC
    WESTL
    3606.0
    [m]
    DC
    RRI
    3608.0
    [m]
    SWC
    WESTL
    3612.0
    [m]
    DC
    RRI
    3618.0
    [m]
    DC
    RRI
    3622.5
    [m]
    SWC
    WESTL
    3624.0
    [m]
    DC
    RRI
    3630.0
    [m]
    DC
    RRI
    3636.0
    [m]
    DC
    RRI
    3642.0
    [m]
    DC
    RRI
    3648.0
    [m]
    DC
    RRI
    3654.0
    [m]
    DC
    RRI
    3660.0
    [m]
    DC
    RRI
    3666.0
    [m]
    DC
    RRI
    3672.0
    [m]
    DC
    RRI
    3676.0
    [m]
    DC
    RRI
    3680.4
    [m]
    C
    RRI
    3685.4
    [m]
    C
    RRI
    3688.9
    [m]
    C
    RRI
    3696.8
    [m]
    C
    RRI
    3701.2
    [m]
    C
    RRI
    3704.1
    [m]
    C
    RRI
    3704.6
    [m]
    C
    RRI
    3707.6
    [m]
    C
    RRI
    3713.8
    [m]
    C
    RRI
    3717.9
    [m]
    C
    RRI
    3725.6
    [m]
    C
    RRI
    3730.6
    [m]
    C
    RRI
    3734.4
    [m]
    C
    RRI

  • Oil samples at the Norwegian Offshore Directorate
    Oil samples at the Norwegian Offshore Directorate
    Test type
    Bottle number
    Top depth
    MD [m]
    Bottom depth
    MD [m]
    Fluid type
    Test time
    Samples available
    DST
    DST1
    0.00
    0.00
    OIL
    03.08.1996 - 00:00
    YES

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.38

  • 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
    20.47

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    3693
    3687
    12.7
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    3.000
    15.100
    136
    Drill stem tests (DST)
    Test number
    Oil
    [Sm3/day]
    Gas
    [Sm3/day]
    Oil density
    [g/cm3]
    Gas grav. rel.air
    GOR
    [m3/m3]
    1.0
    244
    29505
    0.860
    0.690
    121

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    DEL2 HDIL MAC CAL DSL CHT
    1400
    3677
    DSL2 ZDL CN GR
    3670
    3805
    HDIL MAC DSL GR CHT
    3670
    3805
    HEXDIP GR CHT
    1800
    3677
    HEXDIP GR CHT
    3670
    3807
    MAC GR CHT
    1800
    3677
    MWD - DPR2
    810
    1806
    MWD - DPR2A
    1806
    2485
    MWD - DPR2A
    2845
    3668
    RCI GR CHT
    3667
    3765
    RCORE GR CHT
    2461
    3623
    VSP GR
    950
    3655
    VSP GR
    3565
    3800
    ZDL CN DSL CHT
    1800
    3677

  • 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
    371.0
    36
    373.0
    0.00
    LOT
    SURF.COND.
    20
    810.0
    26
    813.0
    1.35
    LOT
    INTERM.
    13 3/8
    1802.0
    17 1/2
    1804.0
    1.78
    LOT
    INTERM.
    9 5/8
    3670.0
    12 1/4
    3674.0
    1.50
    LOT
    LINER
    7
    3805.0
    8 1/2
    3805.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    860
    1.07
    16.0
    ANCO 2000
    1810
    1.30
    18.0
    ANCO 2000
    2040
    1.63
    57.0
    ANCO VERT
    2190
    1.63
    57.0
    ANCO VERT
    2498
    1.72
    52.0
    ANCO VERT
    2526
    1.72
    50.0
    ANCO VERT
    3675
    1.72
    54.0
    ANCO VERT
    3706
    1.20
    21.0
    ANCO VERT
    3805
    1.20
    25.0
    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
    0.27