Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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23.07.2024 - 01:26
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6610/7-2

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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.
    6610/7-2
    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.
    NORWEGIAN SEA
    Well name
    Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    6610/7-2
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    ST 8216 - 115 SP 541
    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.
    385-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.
    200
    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,
    28.08.1983
    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.
    14.03.1984
    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.
    14.03.1986
    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.
    15.06.2005
    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.
    DRY
    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.
    235.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4215.0
    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).
    4213.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    5.2
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    112
    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 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.
    GREY BEDS (INFORMAL)
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    66° 27' 49.61'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    10° 10' 10.92'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7372281.53
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    552123.02
    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.
    26
  • Wellbore history

    General
    Wildcat well 6610/7-2 is located on the Trøndelag Platform outside Mid Norway. The primary objective of the well was to test the hydrocarbon potential of Early Jurassic and Late Triassic sandstones. Secondary objectives were to gather information about the stratigraphy and hydrocarbon potential down to approximately 4200 m.
    Operations and results
    Wildcat well 6610/7-2 was spudded with the semi-submersible installation West Vanguard on 28 August 1983 and drilled to TD at 4215 m in the Triassic Grey Beds. Drilling operations were problematic and took 119 days more than programmed. Excessive reaming of tight spots had to be done during drilling of the 22" hole section. In all the four first hole sections a pilot hole was drilled before underreaming. Nineteen kg junk was recovered from the hole after drilling out of the 13 3/8" casing shoe. Several problems with stuck pipe occurred below 3000 m. At 3526 m the pipe was stuck and was backed off at 3315 m. A cement plug was set from 3292 to 3148 m and the hole was sidetracked from 3212 m. Severe problems with tight hole, was experienced down to 3361 m. The well was drilled with seawater and spud mud down to 701 m, with gypsum/lignosulphonate mud from 701 m to 2160 m. Due to expected salt beds below 2500 m the well was drilled with oil based mud from 2160 m to TD. The oil base used was a Norol product, "hvitolje", a low-aromatic mineral oil C13 - C20 distillate.
    The well encountered several sandstone bodies, the first interpreted as the Egga Informal Unit in Paleocene. Earliest Cretaceous - Late Jurassic were not present in the well. At 1487 m the Early Jurassic Båt Group was encountered with massive and porous sandstone sequence. The Triassic interval 3473 - 4218 m also had some clean sandstone, especially in the upper part. Electrical logs and RFT pressure tests, however, proved all potential reservoirs to be water bearing. Organic geochemical analyses showed that the units with the best source rock properties in this well are the shales and coals of the Early Jurassic Tilje and Åre Formations, which can be classified as rich type II/III source rocks with potential for gas and oil. However, shales in the upper 100 m of the Triassic Grey Beds also have fair to rich contents of organic matter classified as type III kerogen with some potential for gas. The well is immature down to approximately 2300 m, reaches peak oil generation maturity (0.8% Ro) at around 2900 m, while base oil window is considered at around TD in the well. Hence, the Early Jurassic coals and shales are immature in the well position. Free hydrocarbons thought to be due to migration are detected only in a siltstone sample from 1504 m in the Tilje Formation.
    Two cores were cut, one in the Early Jurassic sequence and one in the Grey beds close to TD. No fluid sample was taken. The sample available at the NPD is a sample of the base oil used in the drilling mud.
    The well was permanently abandoned on 14 March 1984 as a dry hole.
    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]
    320.00
    4212.00
  • 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
    1498.0
    1507.0
    [m ]
    2
    4180.0
    4195.0
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    24.0
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES
  • Core photos

    Core photos
    Core photo at depth: 1498-1503m
    Core photo at depth: 1503-1507m
    Core photo at depth: 4180-4186m
    Core photo at depth: 4186-4192m
    Core photo at depth: 4192-4195m
    1498-1503m
    1503-1507m
    4180-4186m
    4186-4192m
    4192-4195m
  • Palynological slides at the Norwegian Offshore Directorate

    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    712.0
    [m]
    SWC
    IKU
    712.0
    [m]
    SWC
    OD
    760.0
    [m]
    SWC
    OD
    806.0
    [m]
    SWC
    OD
    806.0
    [m]
    SWC
    IKU
    888.0
    [m]
    SWC
    OD
    888.0
    [m]
    SWC
    IKU
    938.0
    [m]
    SWC
    IKU
    938.0
    [m]
    SWC
    OD
    986.0
    [m]
    SWC
    OD
    986.0
    [m]
    SWC
    IKU
    990.0
    [m]
    DC
    DONG
    1002.0
    [m]
    SWC
    IKU
    1002.0
    [m]
    SWC
    OD
    1010.0
    [m]
    DC
    DONG
    1030.0
    [m]
    DC
    DONG
    1031.5
    [m]
    SWC
    IKU
    1047.0
    [m]
    SWC
    IKU
    1050.0
    [m]
    DC
    DONG
    1070.0
    [m]
    DC
    DONG
    1090.0
    [m]
    DC
    DONG
    1110.0
    [m]
    DC
    DONG
    1129.0
    [m]
    SWC
    IKU
    1130.0
    [m]
    DC
    DONG
    1150.0
    [m]
    DC
    DONG
    1170.0
    [m]
    DC
    DONG
    1190.0
    [m]
    DC
    DONG
    1206.0
    [m]
    SWC
    IKU
    1209.0
    [m]
    DC
    DONG
    1230.0
    [m]
    DC
    DONG
    1251.0
    [m]
    DC
    DONG
    1255.0
    [m]
    SWC
    IKU
    1263.0
    [m]
    DC
    DONG
    1270.0
    [m]
    SWC
    IKU
    1305.0
    [m]
    SWC
    IKU
    1344.0
    [m]
    SWC
    IKU
    1400.0
    [m]
    SWC
    IKU
    1435.0
    [m]
    SWC
    OD
    1435.0
    [m]
    SWC
    IKU
    1460.0
    [m]
    SWC
    IKU
    1470.0
    [m]
    SWC
    IKU
    1479.0
    [m]
    SWC
    OD
    1482.0
    [m]
    SWC
    OD
    1485.0
    [m]
    SWC
    IKU
    1521.5
    [m]
    SWC
    IKU
    1539.0
    [m]
    DC
    OD
    1560.0
    [m]
    DC
    OD
    1579.0
    [m]
    DC
    OD
    1593.0
    [m]
    DC
    OD
    1629.0
    [m]
    DC
    OD
    1629.3
    [m]
    SWC
    IKU
    1635.3
    [m]
    SWC
    IKU
    1654.5
    [m]
    SWC
    IKU
    1668.0
    [m]
    DC
    OD
    1678.0
    [m]
    SWC
    IKU
    1705.0
    [m]
    SWC
    IKU
    1707.0
    [m]
    DC
    OD
    1723.5
    [m]
    SWC
    IKU
    1746.0
    [m]
    DC
    OD
    1785.0
    [m]
    DC
    OD
    1806.0
    [m]
    DC
    OD
    1851.0
    [m]
    DC
    OD
    1910.0
    [m]
    SWC
    IKU
    1911.0
    [m]
    DC
    OD
    1938.0
    [m]
    DC
    OD
    1971.0
    [m]
    DC
    OD
    1998.0
    [m]
    DC
    OD
    2028.0
    [m]
    DC
    OD
    2061.0
    [m]
    DC
    OD
    2078.0
    [m]
    SWC
    IKU
    2091.0
    [m]
    DC
    OD
    2122.0
    [m]
    DC
    OD
    2151.0
    [m]
    DC
    OD
    2159.0
    [m]
    SWC
    IKU
    2167.0
    [m]
    SWC
    OD
    2171.0
    [m]
    DC
    OD
    2175.0
    [m]
    SWC
    OD
    2189.0
    [m]
    SWC
    OD
    2208.0
    [m]
    DC
    OD
    2223.0
    [m]
    SWC
    IKU
    2226.0
    [m]
    DC
    OD
    2244.0
    [m]
    DC
    OD
    2252.0
    [m]
    SWC
    OD
    2274.0
    [m]
    DC
    OD
    2334.0
    [m]
    DC
    OD
    2355.0
    [m]
    SWC
    OD
    2364.0
    [m]
    DC
    OD
    2377.5
    [m]
    SWC
    OD
    2392.0
    [m]
    SWC
    IKU
    2394.0
    [m]
    DC
    OD
    2430.0
    [m]
    DC
    OD
    2440.0
    [m]
    SWC
    IKU
    2440.0
    [m]
    DC
    DONG
    2446.5
    [m]
    DC
    OD
    2454.0
    [m]
    DC
    OD
    2484.0
    [m]
    DC
    OD
    2497.0
    [m]
    SWC
    OD
    2514.0
    [m]
    DC
    OD
    2541.5
    [m]
    SWC
    IKU
    2544.0
    [m]
    DC
    OD
    2574.0
    [m]
    DC
    OD
    2589.5
    [m]
    SWC
    IKU
    2604.0
    [m]
    DC
    OD
    2634.0
    [m]
    DC
    OD
    2637.0
    [m]
    SWC
    IKU
    2664.0
    [m]
    DC
    OD
    2694.0
    [m]
    DC
    OD
    2724.0
    [m]
    DC
    OD
    2749.5
    [m]
    SWC
    OD
    2784.0
    [m]
    DC
    OD
    2844.0
    [m]
    DC
    OD
    2874.0
    [m]
    DC
    OD
    2904.0
    [m]
    DC
    OD
    2994.0
    [m]
    DC
    OD
    3024.0
    [m]
    DC
    OD
    3054.0
    [m]
    DC
    OD
    3084.0
    [m]
    DC
    OD
    3114.0
    [m]
    DC
    OD
    3144.0
    [m]
    DC
    OD
    3150.0
    [m]
    SWC
    OD
    3174.0
    [m]
    DC
    OD
    3201.0
    [m]
    SWC
    OD
    3204.0
    [m]
    DC
    OD
    3221.0
    [m]
    SWC
    OD
    3234.0
    [m]
    DC
    OD
    3242.0
    [m]
    SWC
    OD
    3261.0
    [m]
    DC
    OD
    3264.0
    [m]
    DC
    OD
    3284.0
    [m]
    DC
    OD
    3294.0
    [m]
    DC
    OD
    3324.0
    [m]
    DC
    OD
    3338.0
    [m]
    SWC
    OD
    3354.0
    [m]
    DC
    OD
    3376.0
    [m]
    SWC
    OD
    3384.0
    [m]
    DC
    OD
    3414.0
    [m]
    DC
    OD
    3444.0
    [m]
    DC
    OD
    3453.5
    [m]
    SWC
    OD
    3474.0
    [m]
    DC
    OD
    3478.5
    [m]
    SWC
    OD
    3534.0
    [m]
    DC
    OD
    3564.0
    [m]
    DC
    OD
    3587.0
    [m]
    SWC
    OD
    3636.0
    [m]
    DC
    OD
    3663.0
    [m]
    DC
    OD
    3693.0
    [m]
    DC
    OD
    3717.0
    [m]
    DC
    OD
    3753.0
    [m]
    DC
    OD
    3774.0
    [m]
    DC
    OD
    3801.0
    [m]
    DC
    OD
    3840.0
    [m]
    DC
    OD
    3864.0
    [m]
    DC
    OD
    3877.0
    [m]
    SWC
    OD
    3894.0
    [m]
    DC
    OD
    3924.0
    [m]
    DC
    OD
    3951.0
    [m]
    DC
    OD
    3966.0
    [m]
    SWC
    IKU
    3984.0
    [m]
    DC
    OD
    4014.0
    [m]
    DC
    OD
    4044.0
    [m]
    DC
    OD
    4074.0
    [m]
    DC
    OD
    4104.0
    [m]
    DC
    OD
    4120.5
    [m]
    SWC
    OD
    4134.0
    [m]
    DC
    OD
    4164.0
    [m]
    DC
    OD
    4194.0
    [m]
    DC
    OD
  • 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
    MUD
    0.00
    0.00
    BASE OIL
    YES
  • Lithostratigraphy

  • Composite logs

    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.91
  • Geochemical information

    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    3.38
    pdf
    4.16
  • Documents – reported by the production licence (period for duty of secrecy expired)

  • Logs

    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    BGT
    701
    1464
    BGT
    701
    1464
    BGT
    1449
    2159
    BGT
    1449
    2162
    CBL VDL GR
    259
    1449
    CBL VDL GR
    908
    2143
    CBL VDL GR
    1755
    3470
    CNT GR
    2140
    3290
    CST
    712
    1460
    CST
    1470
    1752
    CST
    1753
    2159
    CST
    2152
    2667
    CST
    2674
    3478
    CST
    3505
    4205
    CST
    3505
    4088
    DLL MSFL GR SP
    3472
    4215
    HDT GR
    701
    1466
    HDT GR
    3473
    4217
    ISF SONIC MSFL SP CAL GR
    1449
    2177
    ISF SONIC SFL SP CAL GR
    320
    713
    ISF SONIC SP CAL
    701
    1465
    ISF SONIC SP GR
    2177
    4216
    LDL CNL CAL GR
    320
    1466
    LDL CNL CAL NGS
    1449
    4217
    RFT GR
    1490
    2125
    RFT GR
    3514
    4199
    SHDT GR
    1449
    2178
    TDT GR
    2300
    3290
    VELOCITY
    360
    4210
  • 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
    321.0
    36
    321.0
    0.00
    LOT
    SURF.COND.
    20
    701.0
    26
    715.0
    1.53
    LOT
    INTERM.
    16
    1450.0
    22
    1465.0
    1.78
    LOT
    INTERM.
    13 3/8
    2143.0
    17 1/2
    2160.0
    1.76
    LOT
    INTERM.
    9 5/8
    3471.0
    12 1/4
    3486.0
    2.00
    LOT
    OPEN HOLE
    4215.0
    8 1/2
    4215.0
    0.00
    LOT
  • Drilling mud

    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    300
    1.07
    9.0
    WATER BASED
    700
    1.10
    9.0
    18.0
    WATER BASED
    730
    1.12
    WATER BASED
    1110
    1.17
    WATER BASED
    1135
    1.25
    WATER BASED
    1175
    1.31
    WATER BASED
    1225
    1.32
    17.0
    19.0
    WATER BASED
    1300
    1.43
    WATER BASED
    1400
    1.43
    19.0
    19.0
    WATER BASED
    1465
    1.40
    12.0
    11.0
    WATER BASED
    2260
    1.14
    18.0
    18.0
    WATER BASED
    2295
    1.19
    20.0
    15.0
    WATER BASED
    2385
    1.13
    21.0
    16.0
    WATER BASED
    2530
    1.20
    22.0
    20.0
    WATER BASED
    2795
    1.21
    21.0
    19.0
    WATER BASED
    2845
    1.22
    24.0
    20.0
    WATER BASED
    2870
    1.20
    30.0
    16.0
    WATER BASED
    2890
    1.19
    19.0
    17.0
    WATER BASED
    2920
    1.18
    19.0
    14.0
    WATER BASED
    3000
    1.19
    22.0
    14.0
    WATER BASED
    3140
    1.20
    21.0
    10.0
    WATER BASED
    3240
    1.21
    17.0
    22.0
    WATER BASED
    3355
    1.30
    23.0
    15.0
    WATER BASED
    3450
    1.35
    28.0
    17.0
    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
    0.23