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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6406/3-4

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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.
    6406/3-4
    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.
    6406/3-4
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    ST 8710 - 201 SP. 870
    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.
    563-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.
    96
    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,
    25.09.1987
    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.
    29.12.1987
    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.
    29.12.1989
    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.
    18.05.2004
    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 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.
    29.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    295.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4414.0
    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).
    4410.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    6
    Oldest penetrated age
    Age (according to Geologic Time Scale 2004 by F. M. Gradstein, et al. (2004)) of the oldest penetrated formation. May differ from age at TD for example in deviated wellbores. Examples of legal values: CRETACEOUS, EARLY CRETACEOUS, LATE JURASSIC, EARLY PERMIAN, EARLY TRIASSIC, EOCENE.
    EARLY JURASSIC
    Oldest penetrated formation
    Name of the oldest lithostratigraphic unit penetrated by the wellbore. Shown only for released wells. In most wellbores this is formation or group at total depth. May differ from formation or group at TD for example in wellbores drilled with high deviation or through faults. Examples of legal values: AMUNDSEN FM, BALDER FM, BASEMENT, BLODØKS FM, BRYNE FM, BURTON FM, COOK FM, DRAKE FM, DRAUPNE FM, EKOFISK FM, DUNLIN GP.
    TILJE FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    64° 53' 0.11'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    6° 50' 48.55'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7197370.60
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    398030.83
    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.
    1173

  • Wellbore history
    General
    Well 6406/3-4 was drilled to appraise the Trestakk oil discovery made with well 6406/3-2. The primary purpose of the well was to appraise hydrocarbon accumulations of significant amounts in the Middle Jurassic reservoirs down flanks on the Trestakk structure. Secondary objectives were to check for hydrocarbon accumulations deeper than the structural closure of the main field, to verify the geophysical and structural interpretation, and improve the geological, paleontological and geochemical understanding of the area. Total depth was to be 50 m into the Ti1je Formation.
    Operations and results
    Appraisal well 6406/3-4 was spudded with the Dyvi Offshore semi-submersible installation Dyvi Delta on 25 September 1987 and drilled to TD at 4414 m in Early Jurassic Tilje Formation. The well was drilled with seawater and hi-vis pills down to 1179 m, with gypsum/polymer mud from 1179 m to 3984 m, and with gel/lignosulphonate mud from 3984 m to TD. Drilling proceeded without significant problems and there were no signs of shallow gas. An expected pressure build-up started in Paleocene and reached its maximum at 1.50 g/cm3 EMV in the top of Cretaceous. After this the over-pressure decreased and was at 1.42 g/cm3 EMV close to top Jurassic.
    A very weak show was recorded in association with a 2.61% gas peak at 2469 m in the Springar Formation. From 2450 m in the Nise Formation to 2670 m shows were recorded on 50 % of sandstone samples. These shows appeared to be a volatile, light petroleum and continued, gradually disappearing, down to 2750 m in the Nise Formation. Top reservoir came in at 4018 m. There were good shows on cores down to 4078 m, but the reservoir qualities did not seem to be very good due to low permeability. In the Ile Formation poor shows were recorded on cores, indicating tight rocks or residual oil. Residual shows were recorded also in the Tofte Formation, while weak "background" shows were recorded in the Tilje Formation from 4372 m to TD. Geochemical analyses of core sample extracts were consistent with a suggested contact/spill point at 4039 m, and a change in the hydrocarbon shows characteristics was confirmed at 4052 m. The geochemical analyses further confirmed that core chip extracts from the interval 4021.18 m to 4051.94 m in the Garn Formation, and a DST sample from the same formation in the discovery well 6406/3-2 belonged to the same oil family. A proposed OWC at 4074 m was not verified by the geochemical analyses. Results of the well 6406/3-4 indicated that reservoir properties decreased down flanks on the structure. As a result the reserve estimates for the Trestakk structure for oil and associated gas were reduced after drilling this well. Six cores were cut, four in the Garn Formation in the interval 4020 - 4122 m, and two in the Ile Formation in the interval 4156 - 4213 m. Two FMT fluid samples were taken, one at 4105.3 m and another at 4108 m. The well was permanently abandoned on 29 December 1987 as a dry hole with shows.
    Testing
    Four drill stem tests were carried out, one in the Ile Formation (DST 1) and three in the Garn Formation (DST 2, 3 and 4). DST 1 (4175 m to 4198 m) produced 1.8 - 2 m3 fluid/day. No samples were taken. DST 2 (4103 m to 4117 m) produced 60 m3 water/day decreasing to 2.7 m3 water/day. Bottom hole samples were taken. DST 3 (4054 m to 4082 m) produced 7.4 m3 water/day decreasing to 4 m3 water /day. Bottom hole samples were taken. DST 4 (4025 m to 4044 m) produced 2.6 m3/day decreasing to 1.6 m3/day. No sampling.

  • 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]
    1190.00
    4413.00

  • 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
    4020.0
    4048.4
    [m ]
    2
    4048.4
    4076.6
    [m ]
    3
    4076.5
    4094.8
    [m ]
    4
    4094.8
    4122.7
    [m ]
    5
    4156.0
    4184.3
    [m ]
    6
    4185.0
    4212.8
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    158.9
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 4020-4025m
    Core photo at depth: 4025-4030m
    Core photo at depth: 4030-4035m
    Core photo at depth: 4035-4040m
    Core photo at depth: 4040-4045m
    4020-4025m
    4025-4030m
    4030-4035m
    4035-4040m
    4040-4045m
    Core photo at depth: 4045-4048m
    Core photo at depth: 4048-4053m
    Core photo at depth: 4053-4058m
    Core photo at depth: 4058-4063m
    Core photo at depth: 4063-4068m
    4045-4048m
    4048-4053m
    4053-4058m
    4058-4063m
    4063-4068m
    Core photo at depth: 4068-4073m
    Core photo at depth: 4073-4076m
    Core photo at depth: 4076-4081m
    Core photo at depth: 4081-4086m
    Core photo at depth: 4086-4091m
    4068-4073m
    4073-4076m
    4076-4081m
    4081-4086m
    4086-4091m
    Core photo at depth: 4091-4094m
    Core photo at depth: 4094-4099m
    Core photo at depth: 4099-4104m
    Core photo at depth: 4104-4109m
    Core photo at depth: 4109-4114m
    4091-4094m
    4094-4099m
    4099-4104m
    4104-4109m
    4109-4114m
    Core photo at depth: 4114-4119m
    Core photo at depth: 4119-4122m
    Core photo at depth: 4156-4161m
    Core photo at depth: 4161-4166m
    Core photo at depth: 4166-4171m
    4114-4119m
    4119-4122m
    4156-4161m
    4161-4166m
    4166-4171m
    Core photo at depth: 4171-4176m
    Core photo at depth: 4181-4184m
    Core photo at depth: 4176-4181m
    Core photo at depth: 4185-4190m
    Core photo at depth: 4190-4195m
    4171-4176m
    4181-4184m
    4176-4181m
    4185-4190m
    4190-4195m
    Core photo at depth: 4195-4200m
    Core photo at depth: 4200-4205m
    Core photo at depth: 4205-4210m
    Core photo at depth: 4210-4212m
    Core photo at depth:  
    4195-4200m
    4200-4205m
    4205-4210m
    4210-4212m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    2475.0
    [m]
    DC
    RRI
    2490.0
    [m]
    DC
    RRI
    2505.0
    [m]
    DC
    RRI
    2520.0
    [m]
    DC
    RRI
    2535.0
    [m]
    DC
    RRI
    2550.0
    [m]
    DC
    RRI
    2565.0
    [m]
    DC
    RRI
    2580.0
    [m]
    DC
    RRI
    2628.0
    [m]
    DC
    RRI
    2649.0
    [m]
    DC
    RRI
    2655.0
    [m]
    DC
    RRI
    2682.0
    [m]
    DC
    RRI
    2712.0
    [m]
    DC
    RRI
    2724.0
    [m]
    DC
    RRI
    2742.0
    [m]
    DC
    RRI
    2754.0
    [m]
    DC
    RRI
    2772.0
    [m]
    DC
    RRI
    2784.0
    [m]
    DC
    RRI
    2802.0
    [m]
    DC
    RRI
    2814.0
    [m]
    DC
    RRI
    2832.0
    [m]
    DC
    RRI
    2844.0
    [m]
    DC
    RRI
    2874.0
    [m]
    DC
    RRI
    2892.0
    [m]
    DC
    RRI
    2904.0
    [m]
    DC
    RRI
    2944.0
    [m]
    DC
    RRI
    2952.0
    [m]
    DC
    RRI
    2964.0
    [m]
    DC
    RRI
    2982.0
    [m]
    DC
    RRI
    3012.0
    [m]
    DC
    RRI
    3026.0
    [m]
    DC
    RRI
    3042.0
    [m]
    DC
    RRI
    3044.0
    [m]
    DC
    RRI
    3054.0
    [m]
    DC
    RRI
    3084.0
    [m]
    DC
    RRI
    3114.0
    [m]
    DC
    RRI
    3129.0
    [m]
    DC
    RRI
    3144.0
    [m]
    DC
    RRI
    3159.0
    [m]
    DC
    RRI
    3174.0
    [m]
    DC
    RRI
    3184.0
    [m]
    DC
    RRI
    3204.0
    [m]
    DC
    RRI
    3214.0
    [m]
    DC
    RRI
    3234.0
    [m]
    DC
    RRI
    3249.0
    [m]
    DC
    RRI
    3264.0
    [m]
    DC
    RRI
    3279.0
    [m]
    DC
    RRI
    3294.0
    [m]
    DC
    RRI
    3304.0
    [m]
    DC
    RRI
    3324.0
    [m]
    DC
    RRI
    3339.0
    [m]
    DC
    RRI
    3354.0
    [m]
    DC
    RRI
    3369.0
    [m]
    DC
    RRI
    3384.0
    [m]
    DC
    RRI
    3399.0
    [m]
    DC
    RRI
    3414.0
    [m]
    DC
    RRI
    3429.0
    [m]
    DC
    RRI
    3434.0
    [m]
    DC
    RRI
    3444.0
    [m]
    DC
    RRI
    3454.0
    [m]
    DC
    RRI
    3459.0
    [m]
    DC
    RRI
    3474.0
    [m]
    DC
    RRI
    3489.0
    [m]
    DC
    RRI
    3504.0
    [m]
    DC
    RRI
    3519.0
    [m]
    DC
    RRI
    3534.0
    [m]
    DC
    RRI
    3549.0
    [m]
    DC
    RRI
    3564.0
    [m]
    DC
    RRI
    3579.0
    [m]
    DC
    RRI
    3594.0
    [m]
    DC
    RRI
    3604.0
    [m]
    DC
    RRI
    3624.0
    [m]
    DC
    RRI
    3639.0
    [m]
    DC
    RRI
    3644.0
    [m]
    DC
    RRI
    3654.0
    [m]
    DC
    RRI
    3669.0
    [m]
    DC
    RRI
    3684.0
    [m]
    DC
    RRI
    3714.0
    [m]
    DC
    RRI
    3729.0
    [m]
    DC
    RRI
    3744.0
    [m]
    DC
    RRI
    3759.0
    [m]
    DC
    RRI
    3774.0
    [m]
    DC
    RRI
    3789.0
    [m]
    DC
    RRI
    3804.0
    [m]
    DC
    RRI
    3819.0
    [m]
    DC
    RRI
    3834.0
    [m]
    DC
    RRI
    3849.0
    [m]
    DC
    RRI
    3864.0
    [m]
    DC
    RRI
    3879.0
    [m]
    DC
    RRI
    3894.0
    [m]
    DC
    RRI
    3909.0
    [m]
    DC
    RRI
    3924.0
    [m]
    DC
    RRI
    3990.0
    [m]
    DC
    RRI
    3996.0
    [m]
    DC
    RRI
    3999.0
    [m]
    DC
    RRI
    4002.0
    [m]
    DC
    RRI
    4008.0
    [m]
    DC
    RRI
    4011.0
    [m]
    DC
    RRI
    4014.0
    [m]
    DC
    RRI
    4017.0
    [m]
    DC
    RRI
    4023.0
    [m]
    DC
    RRI
    4029.0
    [m]
    C
    RRI
    4030.0
    [m]
    C
    RRI
    4034.0
    [m]
    C
    RRI
    4035.0
    [m]
    C
    RRI
    4041.0
    [m]
    C
    RRI
    4042.0
    [m]
    C
    RRI
    4046.0
    [m]
    C
    RRI
    4049.0
    [m]
    C
    RRI
    4054.0
    [m]
    C
    RRI
    4062.0
    [m]
    C
    RRI
    4068.0
    [m]
    C
    RRI
    4074.0
    [m]
    C
    RRI
    4079.0
    [m]
    C
    RRI
    4080.0
    [m]
    C
    RRI
    4087.0
    [m]
    C
    RRI
    4088.0
    [m]
    C
    RRI
    4089.0
    [m]
    C
    RRI
    4090.0
    [m]
    C
    RRI
    4096.0
    [m]
    C
    RRI
    4100.0
    [m]
    C
    RRI
    4105.0
    [m]
    C
    RRI
    4107.0
    [m]
    C
    RRI
    4114.0
    [m]
    C
    RRI
    4116.0
    [m]
    C
    RRI
    4118.0
    [m]
    C
    RRI
    4121.0
    [m]
    C
    RRI
    4122.0
    [m]
    C
    RRI
    4137.0
    [m]
    DC
    RRI
    4140.0
    [m]
    DC
    RRI
    4152.0
    [m]
    DC
    RRI
    4156.0
    [m]
    C
    RRI
    4158.0
    [m]
    C
    RRI
    4160.0
    [m]
    C
    RRI
    4161.0
    [m]
    C
    RRI
    4166.0
    [m]
    C
    RRI
    4170.0
    [m]
    C
    RRI
    4171.0
    [m]
    C
    RRI
    4174.0
    [m]
    C
    RRI
    4176.0
    [m]
    C
    RRI
    4181.0
    [m]
    C
    RRI
    4182.0
    [m]
    C
    RRI
    4185.0
    [m]
    C
    RRI
    4187.0
    [m]
    C
    RRI
    4192.0
    [m]
    C
    RRI
    4194.0
    [m]
    C
    RRI
    4198.0
    [m]
    C
    RRI
    4204.0
    [m]
    C
    RRI
    4212.0
    [m]
    DC
    RRI
    4221.0
    [m]
    C
    RRI
    4227.0
    [m]
    DC
    RRI
    4230.0
    [m]
    DC
    RRI
    4239.0
    [m]
    DC
    RRI
    4245.0
    [m]
    DC
    RRI
    4260.0
    [m]
    DC
    RRI
    4275.0
    [m]
    DC
    RRI
    4290.0
    [m]
    DC
    RRI
    4305.0
    [m]
    DC
    RRI
    4320.0
    [m]
    DC
    RRI
    4335.0
    [m]
    DC
    RRI
    4350.0
    [m]
    DC
    RRI
    4365.0
    [m]
    DC
    RRI
    4380.0
    [m]
    DC
    RRI
    4395.0
    [m]
    DC
    RRI

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.65

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    1.28

  • 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
    29.39

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    4175
    4198
    25.4
    2.0
    4103
    4117
    7.9
    3.0
    4054
    4082
    4.0
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    43.000
    2.0
    41.000
    3.0
    40.000
    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
    2.0
    3.0

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL VDL
    430
    1330
    CBL VDL
    2500
    3974
    CBL VDL
    3817
    4380
    CDL CN SPL GR
    3974
    4406
    DIFL ACL GR
    3974
    4414
    DIFL ACL GR CDL
    323
    1177
    DIFL ACL GR CDL
    1156
    2665
    DIFL ACL GR CDL
    2648
    3984
    DLL MLL GR
    3974
    4412
    FMTHP GR
    4027
    4391
    FMTHP GR
    4033
    4105
    FMTHP GR
    4103
    4402
    HRDIP
    3974
    4411
    MWD - GR RES ROP DIR
    442
    4341
    VSP
    440
    4350

  • 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
    436.0
    36
    442.0
    0.00
    LOT
    SURF.COND.
    20
    1157.0
    26
    1179.0
    1.60
    LOT
    INTERM.
    13 3/8
    2648.0
    17 1/2
    2692.0
    1.87
    LOT
    INTERM.
    9 5/8
    3970.0
    12 1/4
    3984.0
    1.98
    LOT
    LINER
    7
    4414.0
    8 1/2
    4414.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    375
    1.03
    WATER BASED
    29.12.1987
    442
    1.05
    9400.0
    WATER BASED
    28.09.1987
    442
    1.05
    105.0
    WATER BASED
    28.09.1987
    507
    1.03
    WATER BASED
    28.12.1987
    526
    1.03
    WATER BASED
    28.12.1987
    586
    1.06
    4400.0
    4.5
    WATER BASED
    28.12.1987
    731
    1.05
    120.0
    WATER BASED
    28.09.1987
    1101
    1.05
    100.0
    WATER BASED
    29.09.1987
    1179
    1.05
    95.0
    WATER BASED
    30.09.1987
    1179
    1.05
    100.0
    WATER BASED
    01.10.1987
    1179
    1.05
    100.0
    WATER BASED
    02.10.1987
    1179
    1.05
    100.0
    WATER BASED
    05.10.1987
    1179
    1.06
    1500.0
    5.1
    WATER BASED
    05.10.1987
    1179
    1.05
    1200.0
    3.4
    WATER BASED
    05.10.1987
    1182
    1.06
    1500.0
    4.7
    WATER BASED
    06.10.1987
    1442
    1.12
    1300.0
    4.2
    WATER BASED
    07.10.1987
    1676
    1.20
    1400.0
    4.2
    WATER BASED
    08.10.1987
    1945
    1.50
    1900.0
    4.2
    WATER BASED
    09.10.1987
    2014
    1.24
    16.0
    3.5
    WATER BASED
    23.11.1987
    2387
    1.69
    6300.0
    4.5
    WATER BASED
    22.12.1987
    2387
    1.69
    6300.0
    4.5
    WATER BASED
    23.12.1987
    2450
    1.60
    18.0
    8.0
    WATER BASED
    14.10.1987
    2450
    1.60
    20.0
    8.0
    WATER BASED
    16.10.1987
    2525
    1.69
    5300.0
    4.5
    WATER BASED
    21.12.1987
    2525
    1.70
    5000.0
    3.0
    WATER BASED
    21.12.1987
    2525
    1.69
    5100.0
    3.5
    WATER BASED
    21.12.1987
    2538
    1.69
    6000.0
    4.5
    WATER BASED
    28.12.1987
    2648
    1.53
    17.0
    7.0
    WATER BASED
    22.10.1987
    2648
    1.53
    12.0
    9.0
    WATER BASED
    26.10.1987
    2648
    1.53
    13.0
    9.0
    WATER BASED
    27.10.1987
    2648
    1.53
    16.0
    6.5
    WATER BASED
    02.11.1987
    2648
    1.53
    16.0
    7.0
    WATER BASED
    06.11.1987
    2648
    1.53
    49.0
    5.0
    WATER BASED
    19.10.1987
    2648
    1.53
    50.0
    4.0
    WATER BASED
    19.10.1987
    2648
    1.53
    19.0
    5.0
    WATER BASED
    19.10.1987
    2648
    1.53
    21.0
    6.0
    WATER BASED
    20.10.1987
    2648
    1.53
    19.0
    70.0
    WATER BASED
    21.10.1987
    2648
    1.53
    16.0
    7.0
    WATER BASED
    23.10.1987
    2648
    1.53
    16.0
    7.0
    WATER BASED
    26.10.1987
    2648
    1.53
    16.0
    8.0
    WATER BASED
    26.10.1987
    2648
    1.53
    15.0
    9.0
    WATER BASED
    28.10.1987
    2648
    1.53
    13.0
    8.0
    WATER BASED
    29.10.1987
    2648
    1.53
    18.0
    8.0
    WATER BASED
    30.10.1987
    2648
    1.53
    17.0
    16.0
    WATER BASED
    02.11.1987
    2648
    1.53
    18.0
    7.5
    WATER BASED
    02.11.1987
    2648
    1.53
    17.0
    6.5
    WATER BASED
    03.11.1987
    2648
    1.53
    17.0
    6.0
    WATER BASED
    04.11.1987
    2648
    1.53
    15.0
    6.0
    WATER BASED
    05.11.1987
    2648
    1.53
    53.0
    6.0
    WATER BASED
    09.11.1987
    2648
    1.53
    12.0
    5.0
    WATER BASED
    09.11.1987
    2648
    1.53
    12.0
    4.0
    WATER BASED
    11.11.1987
    2665
    1.60
    20.0
    8.0
    WATER BASED
    16.10.1987
    3175
    1.69
    24.0
    3.5
    WATER BASED
    18.12.1987
    3175
    1.53
    25.0
    2.0
    WATER BASED
    17.12.1987
    3759
    1.53
    23.0
    2.0
    WATER BASED
    16.12.1987
    3970
    1.24
    16.0
    3.5
    WATER BASED
    23.11.1987
    3970
    1.24
    17.0
    3.0
    WATER BASED
    23.11.1987
    3970
    1.24
    18.0
    3.0
    WATER BASED
    23.11.1987
    3970
    1.24
    16.0
    3.0
    WATER BASED
    24.11.1987
    3970
    1.24
    21.0
    4.0
    WATER BASED
    25.11.1987
    3970
    1.23
    15.0
    4.0
    WATER BASED
    18.11.1987
    3970
    1.24
    17.0
    8.0
    WATER BASED
    18.11.1987
    3970
    1.24
    16.0
    8.0
    WATER BASED
    19.11.1987
    3970
    1.24
    17.0
    4.0
    WATER BASED
    20.11.1987
    3970
    1.24
    15.0
    8.0
    WATER BASED
    12.11.1987
    3970
    1.24
    16.0
    6.0
    WATER BASED
    13.11.1987
    3970
    1.24
    14.0
    8.0
    WATER BASED
    16.11.1987
    3970
    1.22
    14.0
    4.0
    WATER BASED
    16.11.1987
    3970
    1.22
    16.0
    8.0
    WATER BASED
    16.11.1987
    4050
    1.24
    19.0
    3.0
    WATER BASED
    14.12.1987
    4050
    1.24
    19.0
    2.5
    WATER BASED
    15.12.1987
    4086
    1.24
    19.0
    3.0
    WATER BASED
    14.12.1987
    4086
    1.24
    18.0
    3.0
    WATER BASED
    08.12.1987
    4086
    1.24
    19.0
    3.0
    WATER BASED
    09.12.1987
    4086
    1.24
    19.0
    3.0
    WATER BASED
    10.12.1987
    4086
    1.24
    18.0
    3.0
    WATER BASED
    11.12.1987
    4098
    1.24
    19.0
    3.0
    WATER BASED
    07.12.1987
    4125
    1.24
    6600.0
    3.0
    WATER BASED
    03.12.1987
    4125
    1.24
    6400.0
    3.0
    WATER BASED
    04.12.1987
    4125
    1.24
    20.0
    3.0
    WATER BASED
    07.12.1987
    4125
    1.24
    19.0
    3.0
    WATER BASED
    07.12.1987
    4125
    1.24
    6100.0
    3.0
    WATER BASED
    02.12.1987
    4156
    1.22
    16.0
    8.0
    WATER BASED
    16.11.1987
    4371
    1.24
    6800.0
    3.5
    WATER BASED
    30.11.1987
    4371
    1.24
    6600.0
    3.5
    WATER BASED
    30.11.1987
    4371
    1.24
    21.0
    4.0
    WATER BASED
    01.12.1987
    4371
    1.24
    6700.0
    3.5
    WATER BASED
    30.11.1987
    4414
    1.24
    17.0
    4.0
    WATER BASED
    20.11.1987

  • 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
    0.22