Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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14.07.2024 - 01:28
Time of last synchronization with Norwegian Offshore Directorate's internal systems

15/9-11

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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.
    15/9-11
    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.
    NORTH 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.
    15/9-11
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    510 - 325 SP 1369
    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.
    303-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.
    97
    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,
    18.09.1981
    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.
    23.12.1981
    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.
    23.12.1983
    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.
    27.05.2009
    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.
    GAS/CONDENSATE
    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.
    PALEOCENE
    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.
    HEIMDAL 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.
    MIDDLE 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.
    HUGIN FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    25.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    88.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2950.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    2.2
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    107
    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.
    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.
    SMITH BANK FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    58° 24' 2.53'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    1° 53' 41.79'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6474001.57
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    435410.76
    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.
    329
  • Wellbore history

    General
    Well 15/11-9 was drilled to appraise the 15/9-9 Sleipner Øst discovery in the south Viking Graben area of the North Sea.
    The primary objective was to delineate the hydrocarbon accumulation found in the Heimdal Formation of the 15/9-Gamma structure. The secondary objective was to test for possible hydrocarbons in Triassic sandstones.
    The well is Reference well for the Lista Formation, the Meile Member, and the Heimdal Formation
    Operations and results
    Appraisal well 15/9-11 was spudded with the semi-submersible installation Ross Rig on 18 September 1981 and drilled to TD at 2950 m in the Triassic Hegre Group. A total of 99 days including a strike was spent on this well. Apart from the strike, which amounted to 22 days of lost operation, there were no severe problems during drilling and testing operations. The well was drilled with sea water and bentonite down to 585 m and with gel/lignosulphonate/seawater mud from 585 m to TD.
    The well proved gas and condensate in Heimdal formation and verified thereby the results from the 15/9-9 well. The gas- water contact was found at 2442 m. Hydrocarbons were found also in the Jurassic Hugin Formation sandstones with a gas-water contact at 2825 m. The TD for the well was then extended from 2650 to 2950 m. No hydrocarbons were found in Triassic sandstones
    Eleven cores were cut in the well. Cores 1 and 2 were cut from 2364 to 2379 m in the Lista Formation. Cores 3 to 11 were cut from 2395 to 2514 m in the Heimdal Formation. The RFT tool was run on wire line and the pressure data supported communication with the 15/9-9 discovery well within the Heimdal Formation, while the Hugin Formation was in a separate pressure regime. Segregated fluid samples were taken at 2387.5 m, in the Heimdal Formation, and at 2812 and 2825.8to 2826.5 m in the Hugin Formation.
    The well was permanently abandoned on 23 December 1981 as a gas/condensate appraisal well.
    Testing
    Three DST was performed. DST 1 tested the Hugin Formation sandstone from 2789.5 - 2830 m. It produced 566000 Sm3 gas and 243 Sm3 condensate / day through a 15.9 mm choke. The condensate density was 0.75 g/cm3 and the gas gravity was 0.74 (air = 1) with 0.5 - 1% CO2. The maximum down hole temperature measured in the test was 103.9 deg C.
    DST 2 tested the Heimdal Formation sandstone in the interval 2432 - 2440 m. It produced 233785 Sm3 gas, 104 Sm3 condensate and 1085 m3 water/ day through a 12.7 mm choke. The oil density was 0.75 g/cm3 and the gas gravity was 0.72 (air = 1) with 0.1 - 0.5% CO2. The maximum down hole temperature measured in the test was 93.3 deg C.
    DST 3 tested the Heimdal Formation sandstone in the interval 2395 - 2415 m. It produced 570867 Sm3 gas and 266 Sm3 condensate / day through a 19.1 mm choke. The oil density was 0.75 g/cm3 and the gas gravity was 0.734 (air = 1) with 0.1 - 0.5% CO2. The maximum down hole temperature measured in the test was 92.2 deg C.
  • Cuttings at the Norwegian Offshore Directorate

    Cuttings at the Norwegian Offshore Directorate
    Cuttings available for sampling?
    NO
    Cuttings at the Norwegian Offshore Directorate
    Cutting sample, top depth [m]
    Cutting samples, bottom depth [m]
    170.00
    2995.00
  • 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
    2364.0
    2370.0
    [m ]
    2
    2370.0
    2374.0
    [m ]
    3
    2395.0
    2406.0
    [m ]
    4
    2406.0
    2423.6
    [m ]
    5
    2424.0
    2429.0
    [m ]
    6
    2436.0
    2449.0
    [m ]
    7
    2449.0
    2457.5
    [m ]
    9
    2473.0
    2491.5
    [m ]
    10
    2492.0
    2505.1
    [m ]
    11
    2506.0
    2513.5
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    104.2
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES
  • Core photos

    Core photos
    Core photo at depth: 2364-2367m
    Core photo at depth: 2367-2370m
    Core photo at depth: 2370-2373m
    Core photo at depth: 2373-2374m
    Core photo at depth: 2395-2398m
    2364-2367m
    2367-2370m
    2370-2373m
    2373-2374m
    2395-2398m
    Core photo at depth: 2398-2401m
    Core photo at depth: 2401-2404m
    Core photo at depth: 2404-2406m
    Core photo at depth: 2406-2409m
    Core photo at depth: 2409-2412m
    2398-2401m
    2401-2404m
    2404-2406m
    2406-2409m
    2409-2412m
    Core photo at depth: 2412-2415m
    Core photo at depth: 2415-2418m
    Core photo at depth: 2418-2421m
    Core photo at depth: 2421-2423m
    Core photo at depth: 2424-2427m
    2412-2415m
    2415-2418m
    2418-2421m
    2421-2423m
    2424-2427m
    Core photo at depth: 2427-2429m
    Core photo at depth: 2436-2439m
    Core photo at depth: 2439-2442m
    Core photo at depth: 2442-2445m
    Core photo at depth: 2445-2448m
    2427-2429m
    2436-2439m
    2439-2442m
    2442-2445m
    2445-2448m
    Core photo at depth: 2448-2449m
    Core photo at depth: 2449-2452m
    Core photo at depth: 2452-2455m
    Core photo at depth: 2455-2457m
    Core photo at depth: 2473-2476m
    2448-2449m
    2449-2452m
    2452-2455m
    2455-2457m
    2473-2476m
    Core photo at depth: 2476-2479m
    Core photo at depth: 2479-2482m
    Core photo at depth: 2482-2485m
    Core photo at depth: 2485-2488m
    Core photo at depth: 2488-2491m
    2476-2479m
    2479-2482m
    2482-2485m
    2485-2488m
    2488-2491m
    Core photo at depth: 2491-2492m
    Core photo at depth: 2492-2495m
    Core photo at depth: 2495-2498m
    Core photo at depth: 2498-2501m
    Core photo at depth: 2501-2504m
    2491-2492m
    2492-2495m
    2495-2498m
    2498-2501m
    2501-2504m
    Core photo at depth: 2504-2505m
    Core photo at depth: 2506-2509m
    Core photo at depth: 2509-2512m
    Core photo at depth: 2512-2513m
    Core photo at depth:  
    2504-2505m
    2506-2509m
    2509-2512m
    2512-2513m
  • Palynological slides at the Norwegian Offshore Directorate

    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    800.0
    [m]
    DC
    FUGRO
    810.0
    [m]
    DC
    FUGRO
    820.0
    [m]
    DC
    FUGRO
    830.0
    [m]
    DC
    FUGRO
    840.0
    [m]
    DC
    FUGRO
    850.0
    [m]
    DC
    FUGRO
    860.0
    [m]
    DC
    FUGRO
    870.0
    [m]
    DC
    FUGRO
    880.0
    [m]
    DC
    FUGRO
    890.0
    [m]
    DC
    FUGRO
    900.0
    [m]
    DC
    FUGRO
    910.0
    [m]
    DC
    FUGRO
    920.0
    [m]
    DC
    FUGRO
    930.0
    [m]
    DC
    FUGRO
    940.0
    [m]
    DC
    FUGRO
    950.0
    [m]
    DC
    FUGRO
    960.0
    [m]
    DC
    FUGRO
    970.0
    [m]
    DC
    FUGRO
    990.0
    [m]
    DC
    FUGRO
    1000.0
    [m]
    DC
    FUGRO
    1010.0
    [m]
    DC
    FUGRO
    1020.0
    [m]
    DC
    FUGRO
    1030.0
    [m]
    DC
    FUGRO
    1040.0
    [m]
    DC
    FUGRO
    1050.0
    [m]
    DC
    FUGRO
    1060.0
    [m]
    DC
    FUGRO
    1070.0
    [m]
    DC
    FUGRO
    1080.0
    [m]
    DC
    FUGRO
    1090.0
    [m]
    DC
    FUGRO
    1100.0
    [m]
    DC
    FUGRO
    2303.0
    [m]
    DC
    2330.0
    [m]
    DC
    2360.0
    [m]
    DC
    2368.9
    [m]
    C
    2390.0
    [m]
    C
    2425.9
    [m]
    C
    2443.9
    [m]
    C
    2504.6
    [m]
    C
    2507.5
    [m]
    C
    2509.0
    [m]
    C
    2513.3
    [m]
    C
    2547.0
    [m]
    C
    2700.0
    [m]
    C
    2730.0
    [m]
    C
    2739.0
    [m]
    DC
    SAGA
    2742.0
    [m]
    DC
    SAGA
    2760.0
    [m]
    DC
    2760.0
    [m]
    DC
    SAGA
    2775.0
    [m]
    DC
    SAGA
    2787.0
    [m]
    DC
    SAGA
    2790.0
    [m]
    DC
    2793.0
    [m]
    DC
    SAGA
    2808.0
    [m]
    DC
    SAGA
    2817.0
    [m]
    DC
    SAGA
    2820.0
    [m]
    DC
    2835.0
    [m]
    DC
    SAGA
    2850.0
    [m]
    DC
    2862.0
    [m]
    DC
    SAGA
    2871.0
    [m]
    DC
    SAGA
    2880.0
    [m]
    DC
    2898.0
    [m]
    DC
    SAGA
    2910.0
    [m]
    DC
    SAGA
    2910.0
    [m]
    DC
    2922.0
    [m]
    DC
    SAGA
    2928.0
    [m]
    DC
    SAGA
    2931.0
    [m]
    DC
    SAGA
    2946.0
    [m]
    DC
    SAGA
    2946.0
    [m]
    DC
    3563.9
    [m]
    DC
  • Oil samples at the Norwegian Offshore Directorate

    Oil samples at the Norwegian Offshore Directorate
    Test type
    Bottle number
    Top depth
    MD [m]
    Bottom depth
    MD [m]
    Fluid type
    Test time
    Samples available
    DST
    TEST1
    2797.00
    2807.00
    01.12.1981 - 21:00
    YES
    DST
    TEST2
    2410.00
    2432.00
    08.12.1980 - 10:30
    YES
    DST
    TEST3
    2395.00
    2415.00
    15.12.1981 - 00:00
    YES
  • Lithostratigraphy

  • Composite logs

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

    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    1.53
    pdf
    0.28
    pdf
    0.48
    pdf
    4.92
  • 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
    17.70
    pdf
    1.58
    pdf
    11.13
    pdf
    1.96
    pdf
    8.29
    pdf
    0.64
    pdf
    27.83
    pdf
    1.71
    pdf
    0.95
    pdf
    0.69
    pdf
    0.48
    pdf
    13.77
    pdf
    3.20
    pdf
    0.18
    pdf
    0.79
    pdf
    2.13
    pdf
    9.01
    pdf
    2.24
    pdf
    1.89
    pdf
    0.42
    pdf
    5.70
    pdf
    1.29
    pdf
    1.44
    pdf
    1.41
    pdf
    0.64
    pdf
    1.26
    pdf
    1.56
    pdf
    0.29
    pdf
    2.05
    pdf
    0.02
    pdf
    0.72
    pdf
    1.45
    pdf
    0.50
    pdf
    0.46
    pdf
    0.21
    pdf
    1.81
    pdf
    2.82
    pdf
    3.56
    pdf
    0.19
    pdf
    0.10
  • Drill stem tests (DST)

    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    2797
    2807
    16.7
    2.0
    2432
    2440
    12.7
    3.0
    2395
    2415
    19.0
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    2.0
    3.0
    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
    238
    517000
    0.750
    0.730
    2172
    2.0
    104
    234000
    0.750
    0.720
    2248
    3.0
    266
    570000
    0.750
    0.734
    2142
  • Logs

    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL GR
    450
    1145
    CBL VDL GR
    900
    2574
    CBL VDL GR
    2490
    2909
    CST
    2170
    2526
    CST
    2610
    2943
    DIPMETER
    2088
    2573
    DIPMETER
    2576
    2855
    DLL MSFL SP GR
    2340
    2540
    FDC CNL GR
    1159
    2947
    FDC GR
    569
    1175
    GEODIP
    2340
    2540
    GEODIP
    2775
    2850
    HDT
    2100
    2849
    ISF BHC GR
    174
    2956
    RFT
    2349
    2517
    RFT
    2790
    2938
    VELOCITY
    685
    2850
  • 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
    174.0
    36
    175.0
    0.00
    LOT
    SURF.COND.
    20
    569.0
    26
    585.0
    1.54
    LOT
    INTERM.
    13 3/8
    1159.0
    17 1/2
    1176.0
    1.77
    LOT
    INTERM.
    9 5/8
    2575.0
    12 1/4
    2590.0
    1.85
    LOT
    LINER
    7
    2950.0
    8 1/2
    2950.0
    0.00
    LOT
  • Drilling mud

    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    465
    1.10
    waterbased
    960
    1.13
    waterbased
    1176
    1.12
    waterbased
    1404
    1.20
    waterbased
    2590
    1.23
    waterbased
  • 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