Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
24.11.2024 - 01:27
Time of last synchronization with Norwegian Offshore Directorate's internal systems

1/6-7

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.
    1/6-7
    Type
    Wellbore type. Legal values: EXPLORATION, DEVELOPMENT, OTHER (see 'Purpose' for more information)
    EXPLORATION
    Purpose
    Final classification of the wellbore.

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

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

    Legal values for other wellbores:
    SOIL DRILLING (drilling in connection with track surveys and other subsurface surveys to investigate the soil conditions prior to placement of facilities),
    SHALLOW GAS (drilling to investigate shallow gas before the first 'real' drilling on the location),
    PILOT (drilling to investigate the geology and fluid connectors for location of the main wellbore),
    SCIENTIFIC (drilling according to Law of Scientific research and exploration),
    STRATIGRAPHIC (driling according to Law of Petroleum activities §2-1).
    WILDCAT
    Status
    Status for the wellbore. Legal values are:

    BLOWOUT: A blowout has occurred in the well.
    CLOSED: A development wellbore that has been closed in a shorter or longer periode. Also applies to development wellbores where drilling is completed, but production/injection has not yet been reported.
    DRILLING: The well is in the drilling phase - can be active drilling, logging, testing or plugging,
    JUNKED: The drilling operation has been terminated due to technical problems.
    P&A: Exploration: The well is plugged and abandoned, and can not be reentered for further use. Development wells: The production/injection from/to the well is stopped and the well is plugged. The wellhead is removed or else made unavailable for further well operations.
    PLUGGED: The wellbore has been plugged, but the upper parts of the wellbore can be re-used. A sidetrack might be drilled at a later stage.
    PRODUCING: It was produced from the wellbore at the time of the operators last monthly report to the Norwegian Offshore Directorate.
    INJECTING: It was injected to the wellbore at the time of the operators last monthly report to the Norwegian Offshore Directorate.
    PREDRILLED: The upper part of the well has been drilled, usually as part of a batch-drilling campaign covering several wellbores.
    RE-CLASS TO DEV: Exploration wellbore that is reclassified to a development wellbore.
    RE-CLASS TO TEST: Exploration wellbore that is reclassified to test production.
    SUSPENDED: The drilling operation in the wellbore has been temporarily stopped. The current plan is to continue drilling later on.
    P&A
    Factmaps in new window
    Main area
    Name of the area on the Norwegian Continental Shelf where the wellbore is located. Legal values: BARENTS SEA, NORWEGIAN SEA, NORTH SEA.
    NORTH SEA
    Well name
    Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    1/6-7
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    CNI/88-4A & SP. 620
    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.
    Conoco Norway Inc.
    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.
    724-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.
    119
    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,
    16.03.1992
    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.
    12.07.1992
    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.
    12.07.1994
    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.
    15.06.2011
    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.
    22.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    68.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4995.0
    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).
    4925.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    31.4
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    182
    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 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.
    HAUGESUND FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    56° 33' 20.01'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 54' 11.18'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6268058.24
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    494043.59
    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.
    1928

  • Wellbore history
    General
    Well 1/6-7 is located in the Feda Graben of the North Sea, approximately mid-way between the Albuskjell and Tommeliten Gamma fields. It was drilled on the flank of a salt diapir. The primary objective of the well was to test the hydrocarbon potential of Late Jurassic sandstones. Two secondary objectives were identified; to test for hydrocarbons in the Cretaceous Chalk and to test for the development and the hydrocarbon potential of Paleocene sands.
    Operations and results
    Wildcat well 1/6-7 was spudded with the semi-submersible installation West Vanguard on 16 March 1992 and drilled to TD at 4995 m (5001 m logger's depth / 4925 m TVD). A 9 7/8" pilot hole was drilled from 170 to 1007m prior to the 26" section to check for possible shallow gas at 311, 351, and 397 m. No shallow gas was seen. MWD check-shots inside the 20" casing (azimuth unreliable) proved that the well had sidetracked in the 26" hole. In the 12 1/4" hole a steerable assembly was run in hole to correct the course. This twisted off, leaving a fish at 3740 m. The well was plugged back to 3550 m and the well was sidetracked from 3650 m. After the sidetrack the azimuth stayed fairly constant in a northwest direction. The inclination, though, increased. In the 12 1/4" hole from 3515 m to 4329 m the angle built from 3.73deg to 13.52deg. The angle kept building in the 8 1/2" hole until a maximum MWD survey of 31.40deg at 4701m. At this depth the bit was pulled out of the hole for an intermediate logging run and to change the BHA to an angle dropping assembly. This assembly dropped the inclination to 24.7deg by TD. At 4878 m, in the top of Sandstone Unit II, a salt water kick was taken. The well was drilled with seawater with viscous pre-hydrated bentonite sweeps down to 1007 m, with inhibitive polymer mud system utilizing WBS-200 wellbore stabilizer to from 1007 m to 1400 m, with PHPA inhibitive polymer mud from 1400 m to 3273 m, and with high temperature polymer system mud from 3273 m to TD.
    Weak to fair shows in the claystone and limestone were seen in several intervals from 2680 to 2950 m (Hordaland Group), and free tarry oil in the mud was observed from 2912 - 2945 m (claystone with stringers of limestone and dolomite). The tarry oil was described as dark brown to black, with a resinous lustre, orange to yellow direct fluorescence, moderate to fast streaming yellowish cut and had a dark brown residue. The Chalk objective was drilled outside of structural closure and top Ekofisk Formation was penetrated at 3278 m (3275 m TVD). Moderate shows were described here in a zone from 3288 to 3293 m with weaker shows continuing down into core #1, and on cuttings further down to 3420 m. The electrical logs indicate an average porosity of 17.5% in this zone. BCU (top Mandal Formation) was penetrated at 4402.5 m (4388.6 m TVD). Two sandstone units of Oxfordian age, Sandstone Unit II (4750 - 4788 m / 4706.4 - 4739.7 m TVD) and Unit I (4879 - 4977 m / 4820 - 4907.5 m TVD) were penetrated. Average porosities of the Units were 16.1 and 21.5 % respectively. Shows in Sandstone Unit II (4750-4788m, Core #2 and #3) were described as very weak to no direct fluorescence, slow even bluish white crush cut, and faint creamy residue fluorescence. Shows in Sandstone Unit I (4879 - 4977 m) appeared with no fluorescence, no cut, minor traces of slow even bluish white crush cut and traces of creamy residue fluorescence. The cuttings in this unit had a good gas odour.
    Three cores were cut with 100, 94.7, and 98.5% recovery, respectively. The first core was cut in the upper part of the Ekofisk Formation (3295 m - 3313.9, m) and the next two in the Haugesund Formation (4754 - 4773 m and 4773 - 4800.57 m respectively) in Sandstone Unit II and into the underlying shale. In order to match the gamma ray log cores #1, #2, and #3 has to be shifted + 1.2 m, +6.5 m, and +5.5 m, respectively. A total of 10 FMT pressure tests and one fluid sample were taken in Sandstone Unit I. Calculated pressure gradient in this sandstone is 0.52 psi/ft (0.12 Bar/m). The fluid sample, at 4884 m, contained water and mud filtrate only.
    The well was permanently abandoned on 12 July 1992 as a dry well with shows.
    Testing
    No drill stem test was performed.

  • Cuttings at the Norwegian Offshore Directorate
    Cuttings at the Norwegian Offshore Directorate
    Cuttings available for sampling?
    YES
    Cuttings at the Norwegian Offshore Directorate
    Cutting sample, top depth [m]
    Cutting samples, bottom depth [m]
    1010.00
    4993.00

  • 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
    3295.0
    3313.8
    [m ]
    2
    4754.0
    4772.0
    [m ]
    3
    4773.0
    4800.6
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    64.4
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 3295-3299m
    Core photo at depth: 3299-3303m
    Core photo at depth: 3303-3307m
    Core photo at depth: 3307-3311m
    Core photo at depth: 3311-3313m
    3295-3299m
    3299-3303m
    3303-3307m
    3307-3311m
    3311-3313m
    Core photo at depth: 4754-4759m
    Core photo at depth: 4759-4764m
    Core photo at depth: 4764-4769m
    Core photo at depth: 4769-4772m
    Core photo at depth: 4773-4778m
    4754-4759m
    4759-4764m
    4764-4769m
    4769-4772m
    4773-4778m
    Core photo at depth: 4778-4783m
    Core photo at depth: 4783-4788m
    Core photo at depth: 4788-4793m
    Core photo at depth: 4793-4798m
    Core photo at depth: 4798-4800m
    4778-4783m
    4783-4788m
    4788-4793m
    4793-4798m
    4798-4800m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    3142.0
    [m]
    DC
    RRI
    3151.0
    [m]
    DC
    RRI
    3160.0
    [m]
    DC
    RRI
    3169.0
    [m]
    DC
    RRI
    3181.0
    [m]
    DC
    RRI
    3190.0
    [m]
    DC
    RRI
    3196.0
    [m]
    DC
    RRI
    3199.0
    [m]
    DC
    RRI
    3211.0
    [m]
    DC
    RRI
    3220.0
    [m]
    DC
    RRI
    3232.0
    [m]
    DC
    RRI
    3241.0
    [m]
    DC
    RRI
    3250.0
    [m]
    DC
    RRI
    3262.0
    [m]
    DC
    RRI
    3272.0
    [m]
    DC
    RRI
    3277.0
    [m]
    DC
    RRI
    3280.0
    [m]
    DC
    RRI
    4402.0
    [m]
    DC
    PETROSTR
    4411.0
    [m]
    DC
    PETROS
    4420.0
    [m]
    DC
    PETROS
    4429.0
    [m]
    DC
    PETROS
    4438.0
    [m]
    DC
    PETROS
    4447.0
    [m]
    DC
    PETROS
    4456.0
    [m]
    DC
    PETROS
    4465.0
    [m]
    DC
    PETROS
    4474.0
    [m]
    DC
    PETROS
    4483.0
    [m]
    DC
    PETROS
    4492.0
    [m]
    DC
    PETROS
    4501.0
    [m]
    DC
    PETROS
    4510.0
    [m]
    DC
    PETROS
    4519.0
    [m]
    DC
    PETROS
    4528.0
    [m]
    DC
    PETROS
    4537.0
    [m]
    DC
    PETROS
    4549.0
    [m]
    DC
    PETROS
    4555.0
    [m]
    DC
    PETROS
    4564.0
    [m]
    DC
    PETROS
    4573.0
    [m]
    DC
    PETROS
    4582.0
    [m]
    DC
    PETROS
    4591.0
    [m]
    DC
    PETROS
    4600.0
    [m]
    DC
    PETROS
    4609.0
    [m]
    DC
    PETROS
    4621.0
    [m]
    DC
    PETROS
    4627.0
    [m]
    DC
    PETROS
    4636.0
    [m]
    DC
    PETROS
    4645.0
    [m]
    DC
    PETROS
    4654.0
    [m]
    DC
    PETROS
    4663.0
    [m]
    DC
    PETROS
    4672.0
    [m]
    DC
    PETROS
    4681.0
    [m]
    DC
    PETROS
    4690.0
    [m]
    DC
    PETROS
    4699.0
    [m]
    DC
    PETROS
    4708.0
    [m]
    DC
    PETROS
    4717.0
    [m]
    DC
    PETROS
    4726.0
    [m]
    DC
    PETROS
    4735.0
    [m]
    DC
    PETROS
    4744.0
    [m]
    DC
    PETROS
    4756.5
    [m]
    C
    PETROS
    4762.4
    [m]
    C
    PETROS
    4769.0
    [m]
    C
    PETROS
    4773.7
    [m]
    C
    PETROS
    4777.2
    [m]
    C
    PETROS
    4781.2
    [m]
    C
    PETROS
    4783.8
    [m]
    C
    PETROS
    4789.6
    [m]
    C
    PETROS
    4795.9
    [m]
    C
    PETROS
    4798.7
    [m]
    C
    PETROS
    4807.0
    [m]
    DC
    PETROS
    4816.0
    [m]
    DC
    PETROS
    4825.0
    [m]
    DC
    PETROS
    4834.0
    [m]
    DC
    PETROS
    4846.0
    [m]
    DC
    PETROS
    4855.0
    [m]
    DC
    PETROS
    4864.0
    [m]
    DC
    PETROS
    4873.0
    [m]
    DC
    PETROS
    4882.0
    [m]
    DC
    PETROS
    4891.0
    [m]
    DC
    PETROS
    4903.0
    [m]
    DC
    PETROS
    4909.0
    [m]
    DC
    PETROS
    4918.0
    [m]
    DC
    PETROS
    4927.0
    [m]
    DC
    PETROS
    4936.0
    [m]
    DC
    PETROS
    4942.0
    [m]
    DC
    PETROS
    4954.0
    [m]
    DC
    PETROS
    4963.0
    [m]
    DC
    PETROS
    4978.0
    [m]
    DC
    PETROS
    4987.0
    [m]
    DC
    PETROS
    4990.0
    [m]
    DC
    PETROS

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    1.11

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.26
    pdf
    7.15

  • 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
    3.11
    pdf
    54.72

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CSG CAL
    0
    4025
    DAC GR
    1000
    3270
    DAC GR
    3262
    4307
    DAC GR
    4263
    4965
    DIFL AC GR
    4930
    5000
    DIFL AC GR SP
    4350
    4965
    DIFL AC ZDL CN GR
    1005
    3273
    DIFL ZDL CN SP GR
    3262
    4358
    DIP GR
    1600
    3274
    DIP GR
    3262
    4360
    DIP GR
    4350
    4969
    DIP GR
    4650
    5001
    DLL MLL AC GR
    420
    1100
    DLL MLL AC GR
    3262
    4361
    DLL MLL GR
    4350
    4968
    FMT
    4663
    4950
    GR AC ZDL
    90
    1001
    MWD - DPR RAW
    92
    4995
    SBT
    2683
    3460
    SWC
    1355
    3265
    SWC
    3280
    4318
    SWC
    4365
    4995
    SWC
    4465
    4988
    VSP
    1010
    4340
    VSP
    4250
    5000
    ZDL CN GR
    4350
    4970
    ZDL CN GR
    4820
    5000

  • 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
    165.0
    36
    167.0
    0.00
    LOT
    INTERM.
    20
    1000.6
    26
    1002.0
    1.81
    LOT
    INTERM.
    13 3/8
    3261.0
    17 1/2
    3263.0
    1.98
    LOT
    INTERM.
    9 7/8
    4346.8
    12 1/4
    4348.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    96
    1.04
    200.0
    WATER BASED
    165
    1.04
    80.0
    WATER BASED
    311
    1.04
    300.0
    WATER BASED
    735
    1.04
    28.0
    WATER BASED
    773
    1.04
    200.0
    WATER BASED
    903
    1.71
    50.0
    WATER BASED
    1003
    1.43
    95.0
    WATER BASED
    1007
    1.11
    45.0
    WATER BASED
    1010
    1.25
    72.0
    WATER BASED
    1280
    1.45
    81.0
    WATER BASED
    1400
    1.59
    67.0
    WATER BASED
    1490
    1.63
    115.0
    WATER BASED
    1680
    1.63
    84.0
    WATER BASED
    1812
    1.63
    69.0
    WATER BASED
    1952
    1.63
    72.0
    WATER BASED
    2100
    1.63
    65.0
    WATER BASED
    2190
    1.63
    68.0
    WATER BASED
    2396
    1.63
    78.0
    WATER BASED
    2414
    1.63
    75.0
    WATER BASED
    2508
    1.65
    82.0
    WATER BASED
    2640
    1.66
    68.0
    WATER BASED
    2802
    1.67
    84.0
    WATER BASED
    2920
    1.67
    89.0
    WATER BASED
    2992
    1.68
    92.0
    WATER BASED
    3079
    1.67
    83.0
    WATER BASED
    3132
    1.67
    100.0
    WATER BASED
    3157
    1.71
    103.0
    WATER BASED
    3224
    1.71
    80.0
    WATER BASED
    3273
    1.65
    43.0
    WATER BASED
    3275
    1.61
    51.0
    WATER BASED
    3335
    1.56
    46.0
    WATER BASED
    3427
    1.56
    48.0
    WATER BASED
    3507
    1.56
    48.0
    WATER BASED
    3550
    1.47
    67.0
    WATER BASED
    3592
    1.47
    47.0
    WATER BASED
    3613
    1.47
    52.0
    WATER BASED
    3625
    1.47
    49.0
    WATER BASED
    3649
    1.47
    48.0
    WATER BASED
    3653
    1.46
    51.0
    WATER BASED
    3655
    1.47
    55.0
    WATER BASED
    3673
    1.47
    48.0
    WATER BASED
    3770
    1.47
    45.0
    WATER BASED
    3827
    1.47
    46.0
    WATER BASED
    3916
    1.47
    39.0
    WATER BASED
    3999
    1.53
    38.0
    WATER BASED
    4059
    1.53
    44.0
    WATER BASED
    4101
    1.53
    44.0
    WATER BASED
    4200
    2.12
    55.0
    WATER BASED
    4223
    1.53
    37.0
    WATER BASED
    4281
    1.53
    37.0
    WATER BASED
    4289
    2.12
    59.0
    WATER BASED
    4331
    1.53
    37.0
    WATER BASED
    4358
    1.57
    43.0
    WATER BASED
    4441
    1.92
    41.0
    WATER BASED
    4526
    1.97
    42.0
    WATER BASED
    4613
    1.97
    46.0
    WATER BASED
    4691
    2.00
    52.0
    WATER BASED
    4710
    2.00
    50.0
    WATER BASED
    4754
    2.00
    50.0
    WATER BASED
    4773
    2.00
    58.0
    WATER BASED
    4801
    2.00
    58.0
    WATER BASED
    4995
    2.12
    60.0
    WATER BASED

  • 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