Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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22.12.2024 - 01:25
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6305/12-2

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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.
    6305/12-2
    Type
    Wellbore type. Legal values: EXPLORATION, DEVELOPMENT, OTHER (see 'Purpose' for more information)
    EXPLORATION
    Purpose
    Final classification of the wellbore.

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

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

    Legal values for other wellbores:
    SOIL DRILLING (drilling in connection with track surveys and other subsurface surveys to investigate the soil conditions prior to placement of facilities),
    SHALLOW GAS (drilling to investigate shallow gas before the first 'real' drilling on the location),
    PILOT (drilling to investigate the geology and fluid connectors for location of the main wellbore),
    SCIENTIFIC (drilling according to Law of Scientific research and exploration),
    STRATIGRAPHIC (driling according to Law of Petroleum activities §2-1).
    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.
    NORWEGIAN SEA
    Well name
    Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    6305/12-2
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    NH 9203-410 & SP. 890
    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.
    Norsk Hydro Produksjon 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.
    772-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.
    63
    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,
    16.10.1993
    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.
    17.12.1993
    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.
    17.12.1995
    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.
    08.08.2005
    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.
    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.
    146.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3162.0
    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).
    3161.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    3.8
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    121
    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.
    PRE-DEVONIAN
    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.
    BASEMENT
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    63° 1' 11.39'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    5° 40' 6.44'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6990772.25
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    635050.51
    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.
    2207

  • Wellbore history
    General
    Well 6305/12-2 is located in the southwestern part of block 6305/12 in the Slørebotn Sub-basin. The primary objective
    was to test the hydrocarbon and reservoir potential of a stratigraphic Cretaceous Wedge Prospect of anticipated Aptian to Cenomanian age. The secondary objective was to test the reservoir quality and hydrocarbon potential of a structural closure at the Base Cretaceous level called the E-prospect.
    Operations and results
    Wildcat well 6305/12-2 was spudded with the semi-submersible installation Deepsea Bergen on 16 October and drilled to TD at 3162 m in the metamorphic basement. A kick occurred at 2973 m, in the top of Middle Jurassic sandstone, requiring increases in mud density to 1.45 sg and resulting in lost circulation further up the hole, most likely into the Paleocene Sandstone unit. After 7" liner was set to 2635 m background gas up to 10.5 %, formation gas peaks to 13.6 % and pumps-off gas peaks to 15.5 % made it necessary to increase the mud density in stages from 1.50 sg to 1.73 sg. The one successful FMT point, at 3000 m, showed formation pressure to be 1.69 sg in a very tight sandstone. The kick and technical problems related to coring led to two technical sidetracks that should be considered when evaluating logs and cores: the first from 2670 m to 2974 m and the second from 2910 m to final TD. The well was drilled with seawater and bentonite down to 437 m and with the ANCO-2000 KCl/glycol mud system from 437 m to TD.
    The mapped stratigraphic wedge supposed to be of Cretaceous age was encountered at 2970 m and proved to be Middle Jurassic sediments. The sediments were gas bearing, but with extremely poor reservoir properties. The possible reservoir in the E - prospect consisted of metamorphic basement with no significant porosity or permeability. Moderate shows were observed in the Late Cretaceous, in sandstone stringers from 2530 m to 2580 m and in limestone and dolomite stringers from 2630 m to 2730 m. Spotted moderate shows were recorded again in thin sandstone stringers in the Early Cretaceous from 2750 m to 2830. Poor to very poor shows were seen from 2965 m 3144.5 m in the Middle Jurassic. The organic geochemical source rock screening was seriously affected by glycols in the mud system, so the only source rocks that could be ascertained with certainty were the coals and carbargillites of the Middle Jurassic. A very thin Late Jurassic shale at 2966 m was not sampled. The well appears to be immature through the Cretaceous and in the oil window from base Cretaceous to TD.
    A total of 6 cores were cut at intervals through the well. Core 1 and 2 were cut in the first sidetrack and cores 3 - 6 were cut in the second sidetrack. One FMT fluid sample at 3001 m recovered water, mud filtrate and a small amount of gas.
    The well was permanently abandoned on 16 December as a well with shows in the Cretaceous and gas in Middle Jurassic tight sands.
    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]
    440.00
    2979.00

  • 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
    2964.0
    2968.3
    [m ]
    2
    2971.0
    2975.0
    [m ]
    3
    2975.0
    2983.5
    [m ]
    4
    3002.0
    3009.6
    [m ]
    5
    3016.0
    3022.8
    [m ]
    6
    3158.0
    3160.7
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    33.9
    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
    440.0
    [m]
    DC
    RRI
    460.0
    [m]
    DC
    RRI
    480.0
    [m]
    DC
    RRI
    500.0
    [m]
    DC
    RRI
    520.0
    [m]
    DC
    RRI
    540.0
    [m]
    DC
    RRI
    560.0
    [m]
    DC
    RRI
    580.0
    [m]
    DC
    RRI
    600.0
    [m]
    DC
    RRI
    620.0
    [m]
    DC
    RRI
    640.0
    [m]
    DC
    RRI
    660.0
    [m]
    DC
    RRI
    680.0
    [m]
    DC
    RRI
    700.0
    [m]
    DC
    RRI
    720.0
    [m]
    DC
    RRI
    740.0
    [m]
    DC
    RRI
    760.0
    [m]
    DC
    RRI
    780.0
    [m]
    DC
    RRI
    800.0
    [m]
    DC
    RRI
    820.0
    [m]
    DC
    RRI
    840.0
    [m]
    DC
    RRI
    860.0
    [m]
    DC
    RRI
    880.0
    [m]
    DC
    RRI
    900.0
    [m]
    DC
    RRI
    920.0
    [m]
    DC
    RRI
    940.0
    [m]
    DC
    RRI
    960.0
    [m]
    DC
    RRI
    980.0
    [m]
    DC
    RRI
    1000.0
    [m]
    DC
    RRI
    1020.0
    [m]
    DC
    RRI
    1040.0
    [m]
    DC
    RRI
    1060.0
    [m]
    DC
    RRI
    1080.0
    [m]
    DC
    RRI
    1100.0
    [m]
    DC
    RRI
    1120.0
    [m]
    DC
    RRI
    1140.0
    [m]
    DC
    RRI
    1160.0
    [m]
    DC
    RRI
    1180.0
    [m]
    DC
    RRI
    1200.0
    [m]
    DC
    RRI
    1220.0
    [m]
    DC
    RRI
    1240.0
    [m]
    DC
    RRI
    1250.0
    [m]
    DC
    RRI
    1270.0
    [m]
    DC
    RRI
    1290.0
    [m]
    DC
    RRI
    1310.0
    [m]
    DC
    RRI
    1330.0
    [m]
    DC
    RRI
    1350.0
    [m]
    DC
    RRI
    1370.0
    [m]
    DC
    RRI
    1390.0
    [m]
    DC
    RRI
    1410.0
    [m]
    DC
    RRI
    1430.0
    [m]
    DC
    RRI
    1450.0
    [m]
    DC
    RRI
    1470.0
    [m]
    DC
    RRI
    1490.0
    [m]
    DC
    RRI
    1510.0
    [m]
    DC
    RRI
    1530.0
    [m]
    DC
    RRI
    1550.0
    [m]
    DC
    RRI
    1570.0
    [m]
    DC
    RRI
    1590.0
    [m]
    DC
    RRI
    1610.0
    [m]
    DC
    RRI
    1630.0
    [m]
    DC
    RRI
    1650.0
    [m]
    DC
    RRI
    1670.0
    [m]
    DC
    RRI
    1710.0
    [m]
    DC
    RRI
    1730.0
    [m]
    DC
    RRI
    1750.0
    [m]
    DC
    RRI
    1770.0
    [m]
    DC
    RRI
    1790.0
    [m]
    DC
    RRI
    1810.0
    [m]
    DC
    RRI
    1830.0
    [m]
    DC
    RRI
    1850.0
    [m]
    DC
    RRI
    1870.0
    [m]
    DC
    RRI
    1890.0
    [m]
    DC
    RRI
    1910.0
    [m]
    DC
    RRI
    1930.0
    [m]
    DC
    RRI
    1940.0
    [m]
    DC
    RRI
    1950.0
    [m]
    DC
    RRI
    1960.0
    [m]
    DC
    RRI
    1970.0
    [m]
    DC
    RRI
    1980.0
    [m]
    DC
    RRI
    1990.0
    [m]
    DC
    RRI
    2000.0
    [m]
    DC
    RRI
    2010.0
    [m]
    DC
    RRI
    2020.0
    [m]
    DC
    RRI
    2030.0
    [m]
    DC
    RRI
    2040.0
    [m]
    DC
    RRI
    2050.0
    [m]
    DC
    RRI
    2060.0
    [m]
    DC
    RRI
    2070.0
    [m]
    DC
    RRI
    2090.0
    [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
    2230.0
    [m]
    DC
    RRI
    2240.0
    [m]
    DC
    RRI
    2250.0
    [m]
    DC
    RRI
    2260.0
    [m]
    DC
    RRI
    2270.0
    [m]
    DC
    RRI
    2280.0
    [m]
    DC
    RRI
    2290.0
    [m]
    DC
    RRI
    2300.0
    [m]
    DC
    RRI
    2310.0
    [m]
    DC
    RRI
    2320.0
    [m]
    DC
    RRI
    2330.0
    [m]
    DC
    RRI
    2340.0
    [m]
    DC
    RRI
    2350.0
    [m]
    DC
    RRI
    2360.0
    [m]
    DC
    RRI
    2370.0
    [m]
    DC
    RRI
    2380.0
    [m]
    DC
    RRI
    2390.0
    [m]
    DC
    RRI
    2400.0
    [m]
    DC
    RRI
    2410.0
    [m]
    DC
    RRI
    2420.0
    [m]
    DC
    RRI
    2430.0
    [m]
    DC
    RRI
    2440.0
    [m]
    DC
    RRI
    2450.0
    [m]
    DC
    RRI
    2460.0
    [m]
    DC
    RRI
    2470.0
    [m]
    DC
    RRI
    2480.0
    [m]
    DC
    RRI
    2490.0
    [m]
    DC
    RRI
    2500.0
    [m]
    DC
    RRI
    2510.0
    [m]
    DC
    RRI
    2520.0
    [m]
    DC
    RRI
    2530.0
    [m]
    DC
    RRI
    2540.0
    [m]
    DC
    RRI
    2550.0
    [m]
    DC
    RRI
    2560.0
    [m]
    DC
    RRI
    2570.0
    [m]
    DC
    RRI
    2580.0
    [m]
    DC
    RRI
    2590.0
    [m]
    DC
    RRI
    2600.0
    [m]
    DC
    RRI
    2610.0
    [m]
    DC
    RRI
    2620.0
    [m]
    DC
    RRI
    2630.0
    [m]
    DC
    RRI
    2640.0
    [m]
    DC
    RRI
    2650.0
    [m]
    DC
    RRI
    2660.0
    [m]
    DC
    RRI
    2670.0
    [m]
    DC
    RRI
    2680.0
    [m]
    DC
    RRI
    2690.0
    [m]
    DC
    RRI
    2700.0
    [m]
    DC
    RRI
    2710.0
    [m]
    DC
    RRI
    2720.0
    [m]
    DC
    RRI
    2730.0
    [m]
    DC
    RRI
    2740.0
    [m]
    DC
    RRI
    2750.0
    [m]
    DC
    RRI
    2760.0
    [m]
    DC
    RRI
    2770.0
    [m]
    DC
    RRI
    2780.0
    [m]
    DC
    RRI
    2790.0
    [m]
    DC
    RRI
    2800.0
    [m]
    DC
    RRI
    2810.0
    [m]
    DC
    RRI
    2830.0
    [m]
    DC
    RRI
    2840.0
    [m]
    DC
    RRI
    2850.0
    [m]
    DC
    RRI
    2860.0
    [m]
    DC
    RRI
    2870.0
    [m]
    DC
    RRI
    2880.0
    [m]
    DC
    OD
    2880.0
    [m]
    DC
    RRI
    2885.0
    [m]
    DC
    OD
    2895.0
    [m]
    DC
    OD
    2895.0
    [m]
    DC
    RRI
    2900.0
    [m]
    DC
    OD
    2900.0
    [m]
    DC
    RRI
    2905.0
    [m]
    DC
    OD
    2905.0
    [m]
    DC
    RRI
    2910.0
    [m]
    DC
    OD
    2910.0
    [m]
    DC
    RRI
    2915.0
    [m]
    DC
    OD
    2915.0
    [m]
    DC
    RRI
    2920.0
    [m]
    DC
    OD
    2920.0
    [m]
    DC
    RRI
    2922.0
    [m]
    DC
    OD
    2925.0
    [m]
    DC
    OD
    2925.0
    [m]
    DC
    RRI
    2930.0
    [m]
    DC
    RRI
    2930.0
    [m]
    DC
    OD
    2935.0
    [m]
    DC
    OD
    2935.0
    [m]
    DC
    RRI
    2940.0
    [m]
    DC
    OD
    2940.0
    [m]
    DC
    RRI
    2945.0
    [m]
    DC
    OD
    2945.0
    [m]
    DC
    RRI
    2950.0
    [m]
    DC
    OD
    2950.0
    [m]
    DC
    RRI
    2955.0
    [m]
    DC
    RRI
    2955.0
    [m]
    DC
    OD
    2962.0
    [m]
    DC
    RRI
    2962.0
    [m]
    DC
    OD
    2964.0
    [m]
    C
    OD
    2965.0
    [m]
    C
    OD
    2965.0
    [m]
    DC
    RRI
    2966.0
    [m]
    C
    OD
    2966.5
    [m]
    C
    RRI
    2966.9
    [m]
    C
    RRI
    2967.0
    [m]
    C
    OD
    2968.0
    [m]
    C
    OD
    2968.3
    [m]
    C
    OD
    2968.3
    [m]
    C
    RRI
    2970.0
    [m]
    DC
    RRI
    2971.8
    [m]
    C
    RRI
    2972.0
    [m]
    DC
    RRI
    2973.7
    [m]
    C
    RRI
    2975.0
    [m]
    C
    RRI
    2983.0
    [m]
    C
    RRI
    3002.0
    [m]
    DC
    RRI
    3008.9
    [m]
    C
    RRI
    3124.0
    [m]
    DC
    RRI
    3147.0
    [m]
    DC
    RRI

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.56

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    1.48

  • 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
    15.88

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBIL SP GR
    2635
    3159
    DIFL ACL ZDL CN SP GR CHT
    398
    1212
    FMT CHT GR
    2966
    3037
    FMT CHT GR
    3001
    3001
    MAC GR
    1200
    3158
    MLL DLL ACL ZDL CN SP GR CHT
    2613
    3158
    MWD - GR DIR
    2670
    3162
    MWD - GR RES DIR
    169
    2973
    SWC GR
    2923
    3135
    SWC GR
    2923
    3081
    VSP
    255
    3155

  • 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
    222.0
    36
    222.0
    0.00
    LOT
    INTERM.
    13 3/8
    398.0
    17 1/2
    400.0
    1.38
    LOT
    INTERM.
    9 5/8
    1229.0
    12 1/4
    1230.0
    1.85
    LOT
    LINER
    7
    2635.0
    8 1/2
    2635.0
    0.00
    LOT
    OPEN HOLE
    3162.0
    6
    3162.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    174
    1.34
    23.0
    10.0
    WATER BASED
    20.12.1993
    185
    1.30
    23.0
    9.5
    WATER BASED
    20.12.1993
    226
    1.03
    WATER BASED
    20.10.1993
    226
    1.03
    WATER BASED
    20.10.1993
    437
    1.50
    WATER BASED
    20.10.1993
    437
    1.50
    WATER BASED
    20.10.1993
    437
    1.20
    WATER BASED
    21.10.1993
    695
    1.10
    16.0
    8.0
    WATER BASED
    26.10.1993
    1238
    1.10
    23.0
    8.5
    WATER BASED
    26.10.1993
    1244
    1.14
    26.0
    10.0
    WATER BASED
    26.10.1993
    1244
    1.14
    22.0
    9.0
    WATER BASED
    27.10.1993
    1244
    1.20
    22.0
    9.5
    WATER BASED
    01.11.1993
    1528
    1.20
    26.0
    15.5
    WATER BASED
    01.11.1993
    1843
    1.20
    30.0
    15.0
    WATER BASED
    01.11.1993
    1988
    1.20
    24.0
    16.0
    WATER BASED
    01.11.1993
    2213
    1.25
    24.0
    15.0
    WATER BASED
    01.11.1993
    2530
    1.82
    22.0
    11.0
    WATER BASED
    14.12.1993
    2530
    1.30
    15.0
    7.5
    WATER BASED
    15.12.1993
    2569
    1.25
    24.0
    16.0
    WATER BASED
    02.11.1993
    2635
    1.50
    28.0
    15.5
    WATER BASED
    17.11.1993
    2635
    1.50
    29.0
    16.0
    WATER BASED
    18.11.1993
    2670
    1.50
    25.0
    15.0
    WATER BASED
    16.11.1993
    2670
    1.50
    26.0
    15.0
    WATER BASED
    16.11.1993
    2670
    1.50
    29.0
    15.5
    WATER BASED
    16.11.1993
    2670
    1.50
    24.0
    12.0
    WATER BASED
    16.11.1993
    2802
    1.50
    30.0
    18.0
    WATER BASED
    19.11.1993
    2866
    1.82
    42.0
    12.0
    WATER BASED
    13.12.1993
    2876
    1.35
    32.0
    20.0
    WATER BASED
    03.11.1993
    2884
    1.35
    31.0
    16.5
    WATER BASED
    08.11.1993
    2899
    1.50
    30.0
    17.5
    WATER BASED
    23.11.1993
    2901
    1.55
    30.0
    17.5
    WATER BASED
    23.11.1993
    2920
    1.35
    34.0
    21.0
    WATER BASED
    08.11.1993
    2934
    1.60
    40.0
    19.0
    WATER BASED
    23.11.1993
    2962
    1.35
    34.0
    21.0
    WATER BASED
    08.11.1993
    2964
    1.63
    41.0
    19.0
    WATER BASED
    23.11.1993
    2964
    1.73
    44.0
    18.0
    WATER BASED
    24.11.1993
    2973
    1.52
    34.0
    21.5
    WATER BASED
    11.11.1993
    2973
    1.50
    34.0
    21.5
    WATER BASED
    11.11.1993
    2973
    1.50
    36.0
    17.0
    WATER BASED
    11.11.1993
    2973
    1.50
    36.0
    17.0
    WATER BASED
    11.11.1993
    2973
    1.50
    24.0
    11.0
    WATER BASED
    12.11.1993
    2973
    1.50
    36.0
    17.0
    WATER BASED
    11.11.1993
    2973
    1.50
    23.0
    12.0
    WATER BASED
    12.11.1993
    2978
    1.73
    44.0
    16.0
    WATER BASED
    26.11.1993
    2979
    1.73
    43.0
    15.5
    WATER BASED
    26.11.1993
    2989
    1.73
    41.0
    12.5
    WATER BASED
    01.12.1993
    3003
    1.73
    41.0
    12.0
    WATER BASED
    02.12.1993
    3016
    1.73
    40.0
    12.5
    WATER BASED
    06.12.1993
    3025
    1.73
    41.0
    13.0
    WATER BASED
    06.12.1993
    3100
    1.73
    41.0
    15.0
    WATER BASED
    06.12.1993
    3143
    1.73
    41.0
    16.5
    WATER BASED
    06.12.1993
    3143
    1.73
    41.0
    15.0
    WATER BASED
    06.12.1993
    3159
    1.73
    41.0
    15.0
    WATER BASED
    07.12.1993
    3162
    1.73
    39.0
    14.5
    WATER BASED
    08.12.1993
    3162
    1.76
    43.0
    15.0
    WATER BASED
    09.12.1993
    3162
    1.76
    WATER BASED
    13.12.1993
    3162
    1.76
    40.0
    15.0
    WATER BASED
    13.12.1993
    3162
    1.76
    38.0
    14.0
    WATER BASED
    13.12.1993

  • 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