Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
12.11.2024 - 01:25
Time of last synchronization with Norwegian Offshore Directorate's internal systems

6506/11-5 S

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.
    6506/11-5 S
    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.
    RE-CLASS TO DEV
    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.
    6506/11-5
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    3D HWM 94-INLINE 4098 & CROSSLINE 1554.
    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.
    859-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.
    62
    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,
    10.09.1996
    Completed date
    Exploration wellbores from moveable facilities:
    For floating facilities - date when anchor handling is started. For jackups - date the jacking-down started. Exploration wellbores from fixed facilities and all development wellbores:
    Date when the wellbore is at total depth, and last casing, liner or screen is set. In case of immediate plugging of the wellbore, completed date equals the date the last plug i set in the wellbore.
    Date when the wellbore is at total depth, and last casing, liner or screen is set. In case of immediate plugging of the wellbore, completed date equals the date the last plug i set in the wellbore.
    10.11.1996
    Release date
    Date when raw data which has been reported to the authorities from the wellbore is not confidential any longer. Normally 2 years after finishing the drilling. May be earlier if the area of the production license is relinquished.
    10.11.1998
    Publication date
    Date quality control of the wellbore information was completed, so it can be published on the internet as a 'Well Data Summary Sheet' wellbore with more information available than other wellbores.
    24.09.2002
    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
    Reclassified to wellbore
    Reentry
    Status whether the wellbore has been re-entered (YES) or not (NO). Re-entered wellbores are not included in the count when wellbores are presented in statistical overviews.
    NO
    Content
    For exploration wellbores, status of discovery.

    Legal values:
    DRY, SHOWS (trace amounts of hydrocarbons), GAS, GAS/CONDENSATE, OIL or OIL/GAS.
    SHOWS (GAS SHOWS, OIL SHOWS or OIL/GAS SHOWS) are detected as fluorescent cut (organic extract), petroleum odour, or visual stain on cuttings or cores, or as increased gas reading on the mud-loggers gas detection equipment.
    Legal values for WILDCAT-CCS and APPRAISAL-CCS: WATER

    For development wellbores, type of produced/injected fluid.
    Legal values:
    WATER, CUTTINGS, NOT AVAILABLE, OIL, GAS/CONDENSATE, OIL/GAS, CO2, GAS, WATER/GAS, NOT APPLICABLE.
    OIL/GAS
    Discovery wellbore
    Indicator which tells if the wellbore made a new discovery. Legal values: YES, NO. Prior to press-release or other information regarding drilling results, the indicator will be “NO” as a default.
    NO
    1st level with HC, age
    Age of lithostratigraphic unit, 1st level, where hydrocarbons were encountered. Examples of legal values: CRETACEOUS, EARLY CRETACEOUS, LATE JURASSIC, EOCENE. See also Norwegian Offshore Directorate bulletins.
    EARLY JURASSIC
    1st level with HC, formation
    Name of lithostartigraphic unit, 1st level, where hydrocarbons were encountered. Shown only for released wells. Examples of legal values: BASEMENT, COOK FM, EKOFISK FM, HEIMDAL FM, SANDNES FM, SOGNEFJORD FM, TARBERT FM, BRENT GP. See also Norwegian Offshore Directorate bulletins.
    TILJE FM
    2nd level with HC, age
    Age of lithostratigraphic unit, 2nd level, where hydrocarbons were encountered. Examples of legal values: CRETACEOUS, EARLY CRETACEOUS, LATE JURASSIC, EOCENE.
    EARLY JURASSIC
    2nd level with HC, formation
    Name of lithostartigraphic unit, 2nd level, where hydrocarbons were encountered. Shown only for released wells. Examples of legal values: BASEMENT, COOK FM, EKOFISK FM, HEIMDAL FM, SANDNES FM, SOGNEFJORD FM, TARBERT FM, BRENT GP.
    ÅRE FM
    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.
    288.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4790.0
    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).
    4729.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    16.7
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    156
    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.
    ÅRE FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    65° 5' 17.5'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    6° 39' 44'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7220497.62
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    390135.87
    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.
    2794

  • Wellbore history
    General
    The main objectives of the well 6506/11-5 S were to appraise hydrocarbons in the Smørbukk Field and collect data on reservoir quality and fluid distribution, to act as an observation well during the long-term test/ interference test of well 6506/12-11 S R, and to be an injector well on the Smørbukk Field.
    Operations and results
    The deviated appraisal well 6506/11-5 S was spudded on 10 September 1996 with the semi-submersible installation "Transocean Searcher" and drilled to a TD of 4740 m in the Åre Formation. The well was drilled with seawater and high viscosity pills down to 622 m, Anco 2000 with glycol from 622 to 2140 m, and with oil based Anco vert from 2140 m to TD. Unexpected high formation pressure was encountered at TD and the mud weight was raised according to this. The Tilje reservoir zone and Åre 2 Formation proved to be hydrocarbon bearing as expected. Three cores (179 meter cored and recovered) were cut from the Tilje and Åre Formations. Two MDT fluid samples were taken at 4674 m in the Tilje Formation. The well was suspended on 10 November 1996 as an observation well for an extended test to be carried out in well 6506/12-11 S R. The well was then re-classified from oil and gas appraisal well to development well 6506/11-G-1 H.
    Testing
    The well was perforated in the Tilje 1.1 Reservoir Zone (4671 - 4685 m) and permanent pressure gauges were installed. Only a short clean up flow was carried out before the pressure gauges were installed so no flow rates were recorded. Due to technical problems with the pressure test string the test was abandoned and no pressure data to confirm communication with well 6506/12-11 S R was obtained.

  • 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]
    3350.00
    4789.00

  • 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
    4540.0
    4609.5
    [m ]
    2
    4609.0
    4656.8
    [m ]
    3
    4657.0
    4718.8
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    179.1
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 4540-4545m
    Core photo at depth: 4545-4550m
    Core photo at depth: 4550-4555m
    Core photo at depth: 4555-4560m
    Core photo at depth: 4560-4565m
    4540-4545m
    4545-4550m
    4550-4555m
    4555-4560m
    4560-4565m
    Core photo at depth: 4565-4570m
    Core photo at depth: 4570-4575m
    Core photo at depth: 4575-4580m
    Core photo at depth: 4580-4585m
    Core photo at depth: 4585-4590m
    4565-4570m
    4570-4575m
    4575-4580m
    4580-4585m
    4585-4590m
    Core photo at depth: 4590-4595m
    Core photo at depth: 4595-4600m
    Core photo at depth: 4600-4605m
    Core photo at depth: 4605-4609m
    Core photo at depth: 4609-4614m
    4590-4595m
    4595-4600m
    4600-4605m
    4605-4609m
    4609-4614m
    Core photo at depth: 4614-4619m
    Core photo at depth: 4619-4624m
    Core photo at depth: 4624-4629m
    Core photo at depth: 4629-4634m
    Core photo at depth: 4634-4639m
    4614-4619m
    4619-4624m
    4624-4629m
    4629-4634m
    4634-4639m
    Core photo at depth: 4639-4644m
    Core photo at depth: 4644-4649m
    Core photo at depth: 4649-4654m
    Core photo at depth: 4654-4656m
    Core photo at depth: 4657-4662m
    4639-4644m
    4644-4649m
    4649-4654m
    4654-4656m
    4657-4662m
    Core photo at depth: 4662-4667m
    Core photo at depth: 4667-4672m
    Core photo at depth: 4672-4677m
    Core photo at depth: 4677-4682m
    Core photo at depth: 4682-4687m
    4662-4667m
    4667-4672m
    4672-4677m
    4677-4682m
    4682-4687m
    Core photo at depth: 4687-4692m
    Core photo at depth: 4692-4697m
    Core photo at depth: 4697-4702m
    Core photo at depth: 4702-4707m
    Core photo at depth: 4707-4712m
    4687-4692m
    4692-4697m
    4697-4702m
    4702-4707m
    4707-4712m
    Core photo at depth: 4712-4717m
    Core photo at depth: 4717-4719m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    4712-4717m
    4717-4719m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    3350.0
    [m]
    DC
    RRI
    3360.0
    [m]
    DC
    RRI
    3380.0
    [m]
    DC
    RRI
    3390.0
    [m]
    DC
    RRI
    3410.0
    [m]
    DC
    RRI
    3420.0
    [m]
    DC
    RRI
    3440.0
    [m]
    DC
    RRI
    3450.0
    [m]
    DC
    RRI
    3470.0
    [m]
    DC
    RRI
    3480.0
    [m]
    DC
    RRI
    3500.0
    [m]
    DC
    RRI
    3510.0
    [m]
    DC
    RRI
    3530.0
    [m]
    DC
    RRI
    3540.0
    [m]
    DC
    RRI
    3560.0
    [m]
    DC
    RRI
    3570.0
    [m]
    DC
    RRI
    3590.0
    [m]
    DC
    RRI
    3600.0
    [m]
    DC
    RRI
    3620.0
    [m]
    DC
    RRI
    3630.0
    [m]
    DC
    RRI
    3650.0
    [m]
    DC
    RRI
    3660.0
    [m]
    DC
    RRI
    3680.0
    [m]
    DC
    RRI
    3690.0
    [m]
    DC
    RRI
    3720.0
    [m]
    DC
    RRI
    3740.0
    [m]
    DC
    RRI
    3750.0
    [m]
    DC
    RRI
    3770.0
    [m]
    DC
    RRI
    3780.0
    [m]
    DC
    RRI
    3800.0
    [m]
    DC
    RRI
    3810.0
    [m]
    DC
    RRI
    3830.0
    [m]
    DC
    RRI
    3840.0
    [m]
    DC
    RRI
    3850.0
    [m]
    DC
    RRI
    3860.0
    [m]
    DC
    RRI
    3880.0
    [m]
    DC
    RRI
    3890.0
    [m]
    DC
    RRI
    3910.0
    [m]
    DC
    RRI
    3920.0
    [m]
    DC
    RRI
    3940.0
    [m]
    DC
    RRI
    3950.0
    [m]
    DC
    RRI
    3970.0
    [m]
    DC
    RRI
    3980.0
    [m]
    DC
    RRI
    4010.0
    [m]
    DC
    RRI
    4030.0
    [m]
    DC
    RRI
    4040.0
    [m]
    DC
    RRI
    4060.0
    [m]
    DC
    RRI
    4077.0
    [m]
    DC
    RRI
    4092.0
    [m]
    DC
    RRI
    4107.0
    [m]
    DC
    RRI
    4122.0
    [m]
    DC
    RRI
    4128.0
    [m]
    DC
    RRI
    4134.0
    [m]
    DC
    RRI
    4140.0
    [m]
    DC
    RRI
    4146.0
    [m]
    DC
    RRI
    4152.0
    [m]
    DC
    RRI
    4155.0
    [m]
    DC
    RRI
    4167.0
    [m]
    DC
    RRI
    4176.0
    [m]
    DC
    RRI
    4182.0
    [m]
    DC
    RRI
    4188.0
    [m]
    DC
    RRI
    4194.0
    [m]
    DC
    RRI
    4203.0
    [m]
    DC
    RRI
    4209.0
    [m]
    DC
    RRI
    4215.0
    [m]
    DC
    RRI
    4221.0
    [m]
    DC
    RRI
    4227.0
    [m]
    DC
    RRI
    4233.0
    [m]
    DC
    RRI
    4245.0
    [m]
    DC
    RRI
    4329.0
    [m]
    DC
    RRI
    4335.0
    [m]
    DC
    RRI
    4341.0
    [m]
    DC
    RRI
    4347.0
    [m]
    DC
    RRI
    4353.0
    [m]
    DC
    RRI
    4359.0
    [m]
    DC
    RRI
    4365.0
    [m]
    DC
    RRI
    4371.0
    [m]
    DC
    RRI
    4377.0
    [m]
    DC
    RRI
    4386.0
    [m]
    DC
    RRI
    4392.0
    [m]
    DC
    RRI
    4470.0
    [m]
    DC
    RRI
    4476.0
    [m]
    DC
    RRI
    4482.0
    [m]
    DC
    RRI
    4488.0
    [m]
    DC
    RRI
    4503.0
    [m]
    DC
    RRI
    4509.0
    [m]
    DC
    RRI
    4515.0
    [m]
    DC
    RRI
    4524.0
    [m]
    DC
    RRI
    4530.0
    [m]
    DC
    RRI
    4536.0
    [m]
    DC
    RRI
    4540.1
    [m]
    C
    RRI
    4552.8
    [m]
    C
    RRI
    4557.4
    [m]
    C
    RRI
    4562.9
    [m]
    C
    RRI
    4567.8
    [m]
    C
    RRI
    4573.2
    [m]
    C
    RRI
    4579.2
    [m]
    C
    RRI
    4586.7
    [m]
    C
    RRI
    4592.3
    [m]
    C
    RRI
    4598.0
    [m]
    DC
    RRI
    4606.6
    [m]
    DC
    RRI
    4611.2
    [m]
    C
    RRI
    4617.3
    [m]
    C
    RRI
    4621.6
    [m]
    C
    RRI
    4626.2
    [m]
    C
    RRI
    4631.7
    [m]
    C
    RRI
    4635.7
    [m]
    C
    RRI
    4641.6
    [m]
    C
    RRI
    4647.4
    [m]
    C
    RRI
    4655.5
    [m]
    C
    RRI
    4659.3
    [m]
    C
    RRI
    4666.4
    [m]
    C
    RRI
    4671.4
    [m]
    C
    RRI
    4676.5
    [m]
    C
    RRI
    4681.4
    [m]
    C
    RRI
    4685.5
    [m]
    C
    RRI
    4688.8
    [m]
    C
    RRI
    4693.4
    [m]
    C
    RRI
    4697.4
    [m]
    C
    RRI
    4701.9
    [m]
    C
    RRI
    4708.9
    [m]
    C
    RRI
    4712.7
    [m]
    C
    RRI
    4718.8
    [m]
    C
    RRI
    4723.0
    [m]
    DC
    RRI
    4729.0
    [m]
    DC
    RRI
    4735.0
    [m]
    DC
    RRI
    4744.0
    [m]
    DC
    RRI
    4750.0
    [m]
    DC
    RRI
    4756.0
    [m]
    DC
    RRI
    4762.0
    [m]
    DC
    RRI
    4768.0
    [m]
    DC
    RRI
    4774.0
    [m]
    DC
    RRI
    4780.0
    [m]
    DC
    RRI
    4786.0
    [m]
    DC
    RRI
    4789.0
    [m]
    DC
    RRI

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.47

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    1.16

  • 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
    30.82

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL VDL GR
    4085
    4756
    DIL LDT CNT AMS GR
    4224
    4793
    DSI NGT AMS
    3300
    4795
    MDT AMS GR
    4250
    4750
    MWD DPR-RAW
    369
    4221
    SDT GR
    4446
    4600
    TRIPPEL COMBO
    4238
    4738
    UBI AMS GR
    4425
    4785
    UBI DSI NGT AMS
    4225
    4785
    VSP
    2030
    4729

  • 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
    369.0
    36
    375.0
    0.00
    LOT
    CONDUCTOR
    20
    616.0
    26
    622.0
    1.44
    LOT
    CONDUCTOR
    13 3/8
    2105.0
    17 1/2
    2140.0
    1.85
    LOT
    CONDUCTOR
    9 5/8
    4225.0
    12 1/4
    4238.0
    1.80
    LOT
    LINER
    7
    4790.0
    8 1/2
    4790.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    1250
    1.25
    16.0
    ANCO 2000
    2126
    1.36
    22.0
    ANCO 2000
    2140
    1.37
    26.0
    ANCO 2000
    2350
    1.70
    50.0
    ANCO VERT
    3249
    1.63
    49.0
    ANCO VERT
    3432
    1.70
    48.0
    ANCO VERT
    3453
    1.70
    50.0
    ANCO VERT
    3842
    1.70
    54.0
    ANCO VERT
    4045
    1.76
    57.0
    ANCO VERT
    4100
    1.76
    57.0
    ANCO VERT
    4142
    1.76
    60.0
    ANCO VERT
    4238
    1.76
    57.0
    ANCO VERT
    4238
    1.22
    30.0
    ANCO VERT
    4239
    1.76
    57.0
    ANCO VERT
    4243
    1.20
    DUMMY
    4281
    1.22
    23.0
    ANCO VERT
    4419
    1.20
    29.0
    ANCO VERT
    4452
    1.20
    30.0
    ANCO VERT
    4530
    1.20
    29.0
    ANCO VERT
    4572
    1.20
    30.0
    ANCO VERT
    4757
    1.20
    30.0
    ANCO VERT
    4790
    1.34
    39.0
    ANCO VERT

  • Pressure plots
    Pressure plots
    The pore pressure data is sourced from well logs if no other source is specified. In some wells where pore pressure logs do not exist, information from Drill stem tests and kicks have been used. The data has been reported to the NPD, and further processed and quality controlled by IHS Markit.
    Pressure plots
    Document name
    Document format
    Document size [MB]
    pdf
    0.28