Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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11.05.2024 - 01:32
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6305/12-1

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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.
    6305/12-1
    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.
    6305/12-1
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    NM 1 - 418 & SP. 1130
    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.
    693-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.
    52
    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,
    29.07.1991
    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.
    18.09.1991
    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.
    18.09.1993
    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.
    176.5
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4302.0
    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).
    4296.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    8.5
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    146
    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.
    LATE TRIASSIC
    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.
    RED BEDS (INFORMAL)
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    63° 1' 25.73'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    5° 47' 23.94'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6991476.94
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    641178.97
    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.
    1808

  • Wellbore history
    General
    Well 6305/12-1 is located in the southwestern part of block 6305/12 in the Slørebotn Sub-basin, approximately 12 km west of the island of Vigra. The C-prospect is an easterly tilted fault block bounded to the west by the Gossa High. The primary objective of the well was to prove hydrocarbons in Early to Middle Jurassic sandstones. Late Triassic sandstones were secondary objectives. The well was designed to leave only non-commercial resources up-dip with a total depth of 4300 m in rocks of presumed Late Triassic age. If the encountered stratigraphy below the base Cretaceous was younger than expected, deeper drilling for stratigraphic information would be considered.
    Operations and results
    Wildcat well 6305/12-1 was spudded with the semi-submersible installation Transocean 8 on 29 July 1991 and drilled to TD at 4302 m in Triassic Red Beds conglomerates. No significant problems were encountered during drilling, which was completed in 55 days compared to prognosed 81 days. The well was drilled with seawater and hi-vis pills down to 721 m and with KCl/polymer mud from 721 m to TD.
    The Egga Informal Sand Unit was encountered at 1804 m. It contained ca 145 m net sand with 19.7% average porosity. Thinly developed sandstones were encountered from 3260 m in the Late Cretaceous Lange Formation and down through to base Early Cretaceous at 3685 m. At 3685 m there was a hiatus from Late Albian (Base Lange Formation) to Bathonian, hence the Late Jurassic source rocks were not present in the well. The Middle Jurassic unit exhibited interbedded thin sandstones, coals and claystones. No shows were recorded while drilling the Egga sandstone, but post-well organic geochemical extraction proved a weak show at 1810 m. The logs showed a water wet Egga reservoir. The Lange sandstones generally displayed poor direct and cut fluorescences while being drilled, and proved later to be oil-bearing, though tight, in subsequent RFT runs. Moveable oil in this section was confirmed by petrophysical evaluation, which detected a 3.75 m net pay with an average of 14.4 % porosity. Chromatographic analysis of drilled gas showed C4's to be present from ca 3150 m in the Late Cretaceous through to the Early Cretaceous and Jurassic, where they gradually diminished towards the base, and disappeared below 3970 m. A trace of oil was observed to be seeping from fractures in a thin coal band at 3692 m in core l in the Middle Jurassic. Organic geochemical analyses showed that the best source rocks were the coals and shales of the Middle Jurassic. In addition a Blodøks Formation Equivalent at 3140 m to 3158 m within the Lange Formation may have some potential (TOC = 2.2% and HI = 165 mg HC/g TOC in a single SWC sample), but this unit is only 18 m thick. The well is immature for petroleum generation down to 2600 m, early mature from 2600 m to 2900 m, and in the oil window from 2900 m to ca 4000 m. Analyses of the oils and extracts showed that the Egga and Lange oils and extracts probably derived from a marine source rock while the oil from the Middle Jurassic was confirmed as a locally sourced coal-bleed.
    Three cores were cut: one in the Middle Jurassic and two in the Triassic Red Beds, including one at TD. Two cased-hole RFT runs were performed, obtaining two sets of fluid samples from 3331 m and 3455.6 m in the Lange Formation sandstones. No reliable pressures were obtained, however small volumes of (ca 0.2 litre) of heavy, emulsified oil were recovered in both samples. A total of 240 sidewall cores were attempted and 160 were recovered.
    The well was permanently abandoned on 18 September 1991. It proved non-commercial volumes of live oil and is classified as a 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]
    730.00
    4300.00

  • 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
    3692.0
    3692.3
    [m ]
    2
    4168.0
    4177.9
    [m ]
    3
    4300.0
    4301.2
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    11.4
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 3692-3697m
    Core photo at depth: 3697-3699m
    Core photo at depth: 4168-4173m
    Core photo at depth: 4173-4177m
    Core photo at depth: 4300-4301m
    3692-3697m
    3697-3699m
    4168-4173m
    4173-4177m
    4300-4301m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    730.0
    [m]
    DC
    RRI
    750.0
    [m]
    SWC
    HYDRO
    760.0
    [m]
    DC
    RRI
    779.0
    [m]
    SWC
    HYDRO
    790.0
    [m]
    DC
    RRI
    810.0
    [m]
    SWC
    HYDRO
    820.0
    [m]
    DC
    RRI
    860.0
    [m]
    SWC
    HYDRO
    860.0
    [m]
    DC
    RRI
    880.0
    [m]
    DC
    RRI
    895.0
    [m]
    SWC
    HYDRO
    910.0
    [m]
    DC
    RRI
    930.0
    [m]
    SWC
    HYDRO
    940.0
    [m]
    DC
    RRI
    950.0
    [m]
    SWC
    HYDRO
    970.0
    [m]
    SWC
    HYDRO
    970.0
    [m]
    DC
    RRI
    990.0
    [m]
    SWC
    HYDRO
    1000.0
    [m]
    SWC
    HYDRO
    1000.0
    [m]
    DC
    RRI
    1010.0
    [m]
    SWC
    HYDRO
    1030.0
    [m]
    SWC
    HYDRO
    1030.0
    [m]
    DC
    RRI
    1060.0
    [m]
    DC
    RRI
    1070.0
    [m]
    SWC
    HYDRO
    1120.0
    [m]
    SWC
    HYDRO
    1140.0
    [m]
    SWC
    HYDRO
    1150.0
    [m]
    DC
    RRI
    1180.0
    [m]
    SWC
    HYDRO
    1180.0
    [m]
    DC
    RRI
    1210.0
    [m]
    DC
    RRI
    1240.0
    [m]
    SWC
    HYDRO
    1240.0
    [m]
    DC
    RRI
    1270.0
    [m]
    DC
    RRI
    1300.0
    [m]
    SWC
    HYDRO
    1300.0
    [m]
    DC
    RRI
    1330.0
    [m]
    SWC
    HYDRO
    1330.0
    [m]
    DC
    RRI
    1360.0
    [m]
    DC
    RRI
    1390.0
    [m]
    DC
    RRI
    1400.0
    [m]
    SWC
    HYDRO
    1420.0
    [m]
    DC
    RRI
    1440.0
    [m]
    SWC
    HYDRO
    1450.0
    [m]
    DC
    RRI
    1480.0
    [m]
    DC
    RRI
    1510.0
    [m]
    DC
    RRI
    1535.0
    [m]
    SWC
    HYDRO
    1540.0
    [m]
    DC
    RRI
    1570.0
    [m]
    SWC
    HYDRO
    1570.0
    [m]
    DC
    RRI
    1615.0
    [m]
    SWC
    HYDRO
    1620.0
    [m]
    DC
    RRI
    1650.0
    [m]
    DC
    RRI
    1660.0
    [m]
    SWC
    HYDRO
    1680.0
    [m]
    DC
    RRI
    1710.0
    [m]
    DC
    RRI
    1740.0
    [m]
    DC
    RRI
    1750.0
    [m]
    SWC
    HYDRO
    1770.0
    [m]
    DC
    RRI
    1780.0
    [m]
    SWC
    HYDRO
    1795.0
    [m]
    SWC
    HYDRO
    1800.0
    [m]
    DC
    RRI
    1804.0
    [m]
    SWC
    HYDRO
    1830.0
    [m]
    DC
    RRI
    1860.0
    [m]
    SWC
    HYDRO
    1860.0
    [m]
    DC
    RRI
    1880.0
    [m]
    SWC
    HYDRO
    1890.0
    [m]
    DC
    RRI
    1900.0
    [m]
    SWC
    HYDRO
    1920.0
    [m]
    DC
    RRI
    1940.0
    [m]
    SWC
    HYDRO
    1950.0
    [m]
    DC
    RRI
    1960.0
    [m]
    SWC
    HYDRO
    1965.0
    [m]
    SWC
    HYDRO
    1980.0
    [m]
    DC
    RRI
    2010.0
    [m]
    DC
    RRI
    2027.0
    [m]
    SWC
    HYDRO
    2031.0
    [m]
    SWC
    HYDRO
    2035.0
    [m]
    SWC
    HYDRO
    2070.0
    [m]
    DC
    RRI
    2096.0
    [m]
    SWC
    HYDRO
    2130.0
    [m]
    DC
    RRI
    2153.0
    [m]
    SWC
    HYDRO
    2180.0
    [m]
    DC
    RRI
    2207.0
    [m]
    SWC
    HYDRO
    2240.0
    [m]
    DC
    RRI
    2268.0
    [m]
    SWC
    HYDRO
    2300.0
    [m]
    DC
    RRI
    2325.0
    [m]
    SWC
    HYDRO
    2360.0
    [m]
    DC
    RRI
    2387.0
    [m]
    SWC
    HYDRO
    2420.0
    [m]
    DC
    RRI
    2448.0
    [m]
    SWC
    HYDRO
    2480.0
    [m]
    DC
    RRI
    2505.0
    [m]
    SWC
    HYDRO
    2540.0
    [m]
    DC
    RRI
    2568.0
    [m]
    SWC
    HYDRO
    2596.0
    [m]
    SWC
    HYDRO
    2608.0
    [m]
    SWC
    HYDRO
    2632.0
    [m]
    SWC
    HYDRO
    2646.0
    [m]
    SWC
    HYDRO
    2658.0
    [m]
    SWC
    HYDRO
    2673.0
    [m]
    SWC
    HYDRO
    2700.0
    [m]
    DC
    RRI
    2739.0
    [m]
    SWC
    HYDRO
    2745.0
    [m]
    SWC
    HYDRO
    2752.0
    [m]
    SWC
    HYDRO
    2780.0
    [m]
    DC
    RRI
    2809.0
    [m]
    SWC
    HYDRO
    2840.0
    [m]
    DC
    RRI
    2870.0
    [m]
    DC
    RRI
    2900.0
    [m]
    DC
    RRI
    2934.0
    [m]
    SWC
    HYDRO
    2960.0
    [m]
    DC
    RRI
    2990.0
    [m]
    DC
    RRI
    3014.0
    [m]
    SWC
    HYDRO
    3020.0
    [m]
    DC
    RRI
    3077.0
    [m]
    SWC
    HYDRO
    3125.0
    [m]
    DC
    RRI
    3155.0
    [m]
    SWC
    HYDRO
    3180.0
    [m]
    SWC
    HYDRO
    3189.0
    [m]
    SWC
    HYDRO
    3196.0
    [m]
    SWC
    HYDRO
    3202.0
    [m]
    SWC
    HYDRO
    3220.0
    [m]
    SWC
    HYDRO
    3256.0
    [m]
    SWC
    HYDRO
    3277.0
    [m]
    SWC
    HYDRO
    3293.0
    [m]
    SWC
    HYDRO
    3314.0
    [m]
    SWC
    HYDRO
    3326.0
    [m]
    SWC
    HYDRO
    3339.0
    [m]
    SWC
    HYDRO
    3379.0
    [m]
    SWC
    HYDRO
    3402.0
    [m]
    SWC
    HYDRO
    3421.0
    [m]
    SWC
    HYDRO
    3452.5
    [m]
    SWC
    HYDRO
    3454.0
    [m]
    SWC
    HYDRO
    3457.0
    [m]
    SWC
    HYDRO
    3497.0
    [m]
    SWC
    HYDRO
    3507.0
    [m]
    SWC
    HYDRO
    3518.0
    [m]
    SWC
    HYDRO
    3550.0
    [m]
    SWC
    HYDRO
    3625.0
    [m]
    SWC
    HYDRO
    3639.0
    [m]
    SWC
    HYDRO
    3648.0
    [m]
    SWC
    HYDRO
    3692.0
    [m]
    C
    RRI
    3697.3
    [m]
    C
    RRI
    3723.0
    [m]
    SWC
    HYDRO
    3743.0
    [m]
    SWC
    HYDRO
    3770.0
    [m]
    SWC
    HYDRO
    3785.0
    [m]
    SWC
    HYDRO
    3800.0
    [m]
    SWC
    HYDRO
    3810.0
    [m]
    SWC
    HYDRO
    3820.0
    [m]
    DC
    RRI
    3822.0
    [m]
    SWC
    HYDRO
    3825.0
    [m]
    DC
    RRI
    3830.0
    [m]
    SWC
    HYDRO
    3847.0
    [m]
    SWC
    HYDRO
    3863.0
    [m]
    SWC
    HYDRO
    3892.0
    [m]
    SWC
    HYDRO
    3905.0
    [m]
    SWC
    HYDRO
    3918.0
    [m]
    SWC
    HYDRO
    3932.0
    [m]
    DC
    RRI
    3937.0
    [m]
    SWC
    HYDRO
    3942.0
    [m]
    DC
    RRI
    3950.0
    [m]
    SWC
    HYDRO
    3965.0
    [m]
    SWC
    HYDRO
    3990.0
    [m]
    SWC
    HYDRO
    4007.0
    [m]
    SWC
    HYDRO
    4037.0
    [m]
    SWC
    HYDRO
    4040.0
    [m]
    DC
    RRI
    4050.0
    [m]
    DC
    RRI
    4067.0
    [m]
    SWC
    HYDRO
    4067.0
    [m]
    DC
    RRI
    4080.0
    [m]
    SWC
    HYDRO
    4150.0
    [m]
    SWC
    HYDRO
    4160.0
    [m]
    SWC
    HYDRO
    4162.0
    [m]
    DC
    RRI
    4169.5
    [m]
    C
    RRI
    4175.0
    [m]
    SWC
    HYDRO

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.60

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    2.67

  • 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
    19.93

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CH RFT
    3331
    3353
    CH RFT
    3454
    3455
    CST GR
    723
    1965
    CST GR
    2027
    3518
    CST GR
    2027
    3518
    CST GR
    3532
    4280
    DIL BHC GP SP
    298
    715
    DIL BHC LDL CNL GR SP MAFL AMS
    1998
    3521
    DIL LSS LDL CNL NGT SP AMS
    3512
    4044
    DIL LSS LDL CNL NGT SP AMS
    3512
    4301
    DIL LSS LDL GR SP AMS
    699
    1967
    FMS4 GR AMS
    1998
    3523
    FMS4 GR AMS
    3512
    4066
    FMS4 GR AMS
    4042
    4304
    MWD - GR RES ROP DIR
    200
    4273
    VSP
    2060
    4280

  • 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
    297.0
    36
    325.0
    0.00
    LOT
    INTERM.
    18 5/8
    700.0
    24
    721.0
    1.78
    LOT
    INTERM.
    13 3/8
    2000.0
    17 1/2
    2017.0
    1.71
    LOT
    INTERM.
    9 5/8
    3510.0
    12 1/4
    3520.0
    2.12
    LOT
    OPEN HOLE
    4302.0
    8 1/2
    4302.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    228
    1.36
    17.0
    9.0
    WATER BASED
    17.09.1991
    228
    1.35
    17.0
    7.0
    WATER BASED
    18.09.1991
    292
    1.04
    23.0
    17.0
    WATER BASED
    01.08.1991
    325
    1.04
    20.0
    17.0
    WATER BASED
    02.08.1991
    325
    1.04
    20.0
    19.0
    WATER BASED
    02.08.1991
    325
    1.05
    18.0
    19.0
    WATER BASED
    06.08.1991
    325
    1.05
    18.0
    20.0
    WATER BASED
    06.08.1991
    413
    1.05
    18.0
    20.0
    WATER BASED
    06.08.1991
    600
    1.36
    17.0
    9.0
    WATER BASED
    16.09.1991
    720
    1.05
    19.0
    19.0
    WATER BASED
    07.08.1991
    720
    1.05
    21.0
    19.0
    WATER BASED
    06.08.1991
    721
    1.25
    23.0
    19.0
    WATER BASED
    08.08.1991
    721
    1.20
    17.0
    12.0
    WATER BASED
    09.08.1991
    1005
    1.20
    15.0
    12.0
    WATER BASED
    12.08.1991
    1473
    1.21
    20.0
    14.0
    WATER BASED
    12.08.1991
    1830
    1.21
    16.0
    11.0
    WATER BASED
    12.08.1991
    1983
    1.22
    18.0
    15.0
    WATER BASED
    14.08.1991
    2017
    1.22
    18.0
    13.0
    WATER BASED
    14.08.1991
    2017
    1.22
    18.0
    14.0
    WATER BASED
    16.08.1991
    2017
    1.22
    18.0
    14.0
    WATER BASED
    16.08.1991
    2178
    1.22
    18.0
    14.0
    WATER BASED
    20.08.1991
    2768
    1.22
    18.0
    16.0
    WATER BASED
    20.08.1991
    3108
    1.23
    19.0
    15.0
    WATER BASED
    20.08.1991
    3280
    1.37
    18.0
    9.0
    WATER BASED
    16.09.1991
    3345
    1.25
    19.0
    17.0
    WATER BASED
    20.08.1991
    3515
    1.26
    18.0
    14.0
    WATER BASED
    22.08.1991
    3520
    1.26
    18.0
    14.0
    WATER BASED
    23.08.1991
    3520
    1.26
    18.0
    14.0
    WATER BASED
    22.08.1991
    3673
    1.30
    17.0
    10.0
    WATER BASED
    27.08.1991
    3701
    1.30
    16.0
    10.0
    WATER BASED
    28.08.1991
    3701
    1.30
    18.0
    10.0
    WATER BASED
    29.08.1991
    3783
    1.30
    17.0
    9.0
    WATER BASED
    02.09.1991
    3905
    1.30
    17.0
    7.0
    WATER BASED
    02.09.1991
    3955
    1.30
    17.0
    7.0
    WATER BASED
    02.09.1991
    4037
    1.30
    17.0
    7.0
    WATER BASED
    02.09.1991
    4112
    1.30
    16.0
    7.0
    WATER BASED
    03.09.1991
    4142
    1.30
    17.0
    9.0
    WATER BASED
    04.09.1991
    4169
    1.36
    18.0
    8.0
    WATER BASED
    06.09.1991
    4178
    1.36
    17.0
    8.0
    WATER BASED
    06.09.1991
    4243
    1.36
    19.0
    8.0
    WATER BASED
    10.09.1991
    4300
    1.38
    20.0
    9.0
    WATER BASED
    10.09.1991
    4300
    1.37
    20.0
    9.0
    WATER BASED
    10.09.1991
    4300
    1.37
    20.0
    9.0
    WATER BASED
    10.09.1991
    4300
    1.36
    19.0
    7.0
    WATER BASED
    12.09.1991
    4300
    1.37
    20.0
    8.0
    WATER BASED
    12.09.1991
    4302
    1.37
    18.0
    10.0
    WATER BASED
    16.09.1991
    4302
    1.37
    18.0
    9.0
    WATER BASED
    16.09.1991