Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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05.11.2024 - 01:27
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6507/8-1

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  • General information
    General information
    Attribute Value
    Wellbore name
    Official name of wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    6507/8-1
    Type
    Wellbore type. Legal values: EXPLORATION, DEVELOPMENT, OTHER (see 'Purpose' for more information)
    EXPLORATION
    Purpose
    Final classification of the wellbore.

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

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

    Legal values for other wellbores:
    SOIL DRILLING (drilling in connection with track surveys and other subsurface surveys to investigate the soil conditions prior to placement of facilities),
    SHALLOW GAS (drilling to investigate shallow gas before the first 'real' drilling on the location),
    PILOT (drilling to investigate the geology and fluid connectors for location of the main wellbore),
    SCIENTIFIC (drilling according to Law of Scientific research and exploration),
    STRATIGRAPHIC (driling according to Law of Petroleum activities §2-1).
    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.
    6507/8-1
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    CN 8502 - 518 SP. 127
    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.
    529-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.
    43
    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,
    28.10.1986
    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.
    09.12.1986
    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.
    09.12.1988
    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.
    17.09.2007
    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/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.
    MIDDLE 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.
    FANGST GP
    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.
    TILJE FM
    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.
    342.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2600.0
    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).
    2600.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    2.6
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    86
    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° 18' 35.03'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    7° 20' 52.8'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7244164.64
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    423003.38
    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.
    933

  • Wellbore history
    General
    Well 6507/8-1 was drilled on the eastern part of the Heidrun Discovery. The primary objective was to ascertain that the Heidrun field extension into the 6507/8 block and to verify reserve calculations. Secondary objectives were to verify geological model and structural interpretation, and define oil water contact in the Tilje Formation. It was also intended to provide more information on reservoir characteristics and hydrocarbon fluids, and maximum input of data for reservoir simulation studies. The Fangst Group was expected at 2245 m, and the Tilje Formation at 2340 m. Prognosed TD was 2590 m.
    Operations and results
    Wildcat well 6507/8-1 was spudded with the semi-submersible installation Dyvi Delta on and drilled to TD at 2600 m in Early Jurassic sediments of the Åre Formation. Drilling proceeded without significant problems. The well was drilled with seawater and hi-vis pills down to 1063 m, with KCl/polymer mud from 1063 m to 2235 m, and with gel/polymer/lingo mud from 2235 m to TD.
    The only oil shows reported above the target reservoir were on sandstone in a cuttings sample at 2235, and on limestone in a SWC at 2238 m, both samples from the Melke Formation. The Middle Jurassic Fangst Group was penetrated at 2248 m and the Early Jurassic Tilje Formation at 2386.5 m. These reservoir sandstones were found to be hydrocarbon bearing with a gas/oil contact at 2312 m and an oil/water contact at 2480 m.
    A total of 9 cores were cut from 2249 m to 2469 m in the Garn, Not, Ile, Ror, and Tilje Formations. Core no 1 from the Garn Formation was loose sand and was lost on the drill floor while recovering from core barrel. One relatively good RFT fluid sample was taken at 2317 m. It contained oil with a density of 0.88 g/cc (29 deg API).
    The well was permanently abandoned on 9 December 1986 as a gas and oil appraisal.
    Testing
    Two DST tests were performed in the Tilje Formation.
    DST 1 tested the interval 2444 - 2463 m and produced 715 Sm3 oil and 31460 Sm3 gas /day through a 3.81 cm choke. The GOR was 44 Sm3/Sm3, the stock tank oil gravity was 0.933 g/cm3 (22.8 deg API), and the gas gravity was 0.600 (air=1). This test produced no sand.
    DST 2 tested the interval 2386.4 -2405.4 m and produced 906 Sm3 oil and 50080 Sm3 gas /day through a 1.91 cm choke. The GOR was 55 Sm3/Sm3, the stock tank oil gravity was 0.917 g/cm3 (22.8 deg API), and the gas gravity was 0.615 (air=1) with 0.5 ppm H2S and 1.5 % CO2. This test also produced some sand. The down-hole temperatures recorded during the tests were 84.9 and 81 deg C in DST 1 and DST 2, respectively.

  • 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]
    1050.00
    2600.00

  • 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
    2
    2262.0
    2272.3
    [m ]
    3
    2290.0
    2314.5
    [m ]
    4
    2316.0
    2343.9
    [m ]
    5
    2369.0
    2386.9
    [m ]
    6
    2398.0
    2411.6
    [m ]
    7
    2417.0
    2434.3
    [m ]
    8
    2439.0
    2466.9
    [m ]
    9
    2467.0
    2494.8
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    167.1
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 2267-2271m
    Core photo at depth: 2262-2266m
    Core photo at depth: 2272-2293m
    Core photo at depth: 2294-2298m
    Core photo at depth: 2299-2303m
    2267-2271m
    2262-2266m
    2272-2293m
    2294-2298m
    2299-2303m
    Core photo at depth: 2304-2308m
    Core photo at depth: 2309-2313m
    Core photo at depth: 2314-2319m
    Core photo at depth: 2320-2324m
    Core photo at depth: 2325-2329m
    2304-2308m
    2309-2313m
    2314-2319m
    2320-2324m
    2325-2329m
    Core photo at depth: 2330-2334m
    Core photo at depth: 2335-2339m
    Core photo at depth: 2340-2369m
    Core photo at depth: 2370-2374m
    Core photo at depth: 2375-2379m
    2330-2334m
    2335-2339m
    2340-2369m
    2370-2374m
    2375-2379m
    Core photo at depth: 2380-2384m
    Core photo at depth: 2385-2400m
    Core photo at depth: 2401-2405m
    Core photo at depth: 2406-2410m
    Core photo at depth: 2411-2420m
    2380-2384m
    2385-2400m
    2401-2405m
    2406-2410m
    2411-2420m
    Core photo at depth: 2421-2425m
    Core photo at depth: 2426-2430m
    Core photo at depth: 2431-2439m
    Core photo at depth: 2440-2444m
    Core photo at depth: 2445-2449m
    2421-2425m
    2426-2430m
    2431-2439m
    2440-2444m
    2445-2449m
    Core photo at depth: 2450-2454m
    Core photo at depth: 2455-2459m
    Core photo at depth: 2460-2464m
    Core photo at depth: 2465-2469m
    Core photo at depth: 2470-2474m
    2450-2454m
    2455-2459m
    2460-2464m
    2465-2469m
    2470-2474m
    Core photo at depth: 2475-2479m
    Core photo at depth: 2480-2484m
    Core photo at depth: 2485-2489m
    Core photo at depth: 2490-2494m
    Core photo at depth:  
    2475-2479m
    2480-2484m
    2485-2489m
    2490-2494m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1700.0
    [m]
    DC
    STATO
    1730.0
    [m]
    DC
    STATO
    1740.0
    [m]
    DC
    STATO
    1760.0
    [m]
    DC
    STATO
    1770.0
    [m]
    DC
    STATO
    1790.0
    [m]
    DC
    STATO
    1800.0
    [m]
    DC
    STATO
    1820.0
    [m]
    DC
    STATO
    1830.0
    [m]
    DC
    STATO
    1850.0
    [m]
    DC
    STATO
    1860.0
    [m]
    DC
    STATO
    1880.0
    [m]
    DC
    STATO
    1890.0
    [m]
    DC
    STATO
    1910.0
    [m]
    DC
    STATO
    1920.0
    [m]
    DC
    STATO
    1940.0
    [m]
    DC
    STATO
    1950.0
    [m]
    DC
    STATO
    1970.0
    [m]
    DC
    STATO
    1980.0
    [m]
    DC
    STATO
    2000.0
    [m]
    DC
    STATO
    2010.0
    [m]
    DC
    STATO
    2030.0
    [m]
    DC
    STATO
    2040.0
    [m]
    DC
    STATO
    2060.0
    [m]
    DC
    STATO
    2070.0
    [m]
    DC
    STATO
    2090.0
    [m]
    DC
    STATO
    2100.0
    [m]
    DC
    STATO
    2120.0
    [m]
    DC
    STATO
    2130.0
    [m]
    DC
    STATO
    2150.0
    [m]
    DC
    STATO
    2160.0
    [m]
    DC
    STATO
    2180.0
    [m]
    DC
    STATO
    2190.0
    [m]
    DC
    STATO
    2210.0
    [m]
    DC
    STATO
    2220.0
    [m]
    DC
    STATO
    2223.0
    [m]
    SWC
    STATO
    2227.0
    [m]
    SWC
    STATO
    2234.0
    [m]
    SWC
    STATO
    2239.0
    [m]
    SWC
    STATO
    2244.0
    [m]
    SWC
    STATO
    2247.0
    [m]
    SWC
    STATO
    2266.0
    [m]
    SWC
    STATO
    2271.4
    [m]
    C
    STATO
    2298.6
    [m]
    C
    STATO
    2305.8
    [m]
    C
    STATO
    2323.1
    [m]
    C
    STATO
    2343.7
    [m]
    C
    STATO
    2350.0
    [m]
    DC
    STATO
    2361.0
    [m]
    DC
    STATO
    2372.2
    [m]
    C
    STATO
    2383.6
    [m]
    C
    STATO
    2398.5
    [m]
    C
    STATO
    2403.8
    [m]
    C
    STATO
    2418.9
    [m]
    C
    STATO
    2426.5
    [m]
    C
    STATO
    2444.4
    [m]
    C
    STATO
    2454.7
    [m]
    C
    STATO
    2463.8
    [m]
    C
    STATO
    2477.8
    [m]
    C
    STATO
    2489.5
    [m]
    C
    STATO
    2499.0
    [m]
    DC
    STATO
    2505.0
    [m]
    DC
    STATO
    2511.0
    [m]
    DC
    STATO
    2517.0
    [m]
    DC
    STATO
    2529.0
    [m]
    DC
    STATO
    2535.0
    [m]
    DC
    STATO
    2541.0
    [m]
    DC
    STATO
    2553.0
    [m]
    DC
    STATO
    2565.0
    [m]
    DC
    STATO
    2577.0
    [m]
    DC
    STATO
    2595.0
    [m]
    DC
    STATO
    2600.0
    [m]
    DC
    STATO

  • 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
    DST1
    2444.00
    2462.50
    30.11.1986 - 00:00
    YES
    DST
    DST2
    2386.00
    2406.00
    04.12.1986 - 00:00
    YES

  • Lithostratigraphy
    Lithostratigraphy
    Top depth [mMD RKB]
    Lithostrat. unit
    371
    1462
    1885
    1885
    1970
    1970
    2020
    2060
    2233
    2233
    2248
    2248
    2294
    2307
    2324
    2324
    2387
    2559

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.36
    pdf
    1.17
    pdf
    0.09

  • 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
    9.60
    pdf
    1.73

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    2444
    2463
    38.1
    2.0
    2386
    2406
    19.1
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    3.000
    2.000
    17.000
    85
    2.0
    6.000
    5.000
    81
    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
    715
    31460
    0.932
    0.600
    44
    2.0
    906
    50080
    0.925
    55

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL VDL GR
    900
    2214
    CBL VDL GR
    2063
    2552
    CBL VDL GR
    2240
    2421
    CST GR
    2232
    2241
    DITE SDT GR
    2217
    2596
    DLL MSFL GR
    2217
    2591
    LDL CNL GR
    2217
    2600
    MWD - GR RES DIR
    371
    2600
    NGS
    2217
    2600
    RFT
    2250
    2580
    RFT HP GR
    2250
    2580
    RLL
    1033
    2600
    SDT GR
    1185
    2217
    SHDT GR
    2217
    2600
    VELOCITY
    1000
    2600

  • 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
    444.0
    36
    610.0
    0.00
    LOT
    INTERM.
    13 3/8
    1033.0
    17 1/2
    1050.0
    1.64
    LOT
    INTERM.
    9 5/8
    2217.0
    12 1/4
    2235.0
    1.60
    LOT
    LINER
    7
    2598.5
    8 1/2
    2600.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    1053
    1.12
    6200.0
    6.8
    WATER BASED
    04.11.1986
    1398
    1.14
    6300.0
    5.9
    WATER BASED
    05.11.1986
    1675
    1.35
    6000.0
    6.3
    WATER BASED
    06.11.1986
    1700
    1.35
    5100.0
    4.7
    WATER BASED
    10.11.1986
    2131
    1.35
    5500.0
    5.9
    WATER BASED
    07.11.1986
    2217
    1.20
    9999.0
    6.3
    WATER BASED
    12.11.1986
    2217
    1.21
    9999.0
    6.3
    WATER BASED
    17.11.1986
    2217
    1.20
    9500.0
    5.5
    WATER BASED
    18.11.1986
    2217
    1.20
    6.3
    WATER BASED
    19.11.1986
    2217
    1.20
    2000.0
    4.2
    WATER BASED
    24.11.1986
    2217
    1.20
    1500.0
    4.7
    WATER BASED
    24.11.1986
    2217
    0.00
    1200.0
    3.5
    WATERBASED
    27.11.1986
    2217
    1.20
    3900.0
    3.0
    WATER BASED
    28.11.1986
    2217
    1.20
    9000.0
    5.5
    WATER BASED
    13.11.1986
    2217
    1.20
    9999.0
    6.3
    WATER BASED
    14.11.1986
    2217
    1.20
    9500.0
    5.9
    WATER BASED
    17.11.1986
    2217
    0.00
    1500.0
    3.4
    WATERBASED
    25.11.1986
    2217
    0.00
    1400.0
    3.8
    WATERBASED
    26.11.1986
    2235
    1.35
    5000.0
    3.8
    WATER BASED
    10.11.1986
    2262
    1.20
    3600.0
    6.8
    WATER BASED
    11.11.1986

  • 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
    0.27