Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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21.11.2024 - 01:28
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34/4-6

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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.
    34/4-6
    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.
    34/4-6
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    SG 8420 - 198 SP. 525
    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.
    Saga Petroleum ASA
    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.
    497-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.
    87
    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,
    31.12.1985
    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.
    27.03.1986
    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.
    27.03.1988
    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.
    26.10.2009
    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.
    OIL
    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.
    LATE TRIASSIC
    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.
    LUNDE FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    26.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    373.5
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3282.0
    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).
    3281.0
    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.
    113
    Oldest penetrated age
    Age (according to Geologic Time Scale 2004 by F. M. Gradstein, et al. (2004)) of the oldest penetrated formation. May differ from age at TD for example in deviated wellbores. Examples of legal values: CRETACEOUS, EARLY CRETACEOUS, LATE JURASSIC, EARLY PERMIAN, EARLY TRIASSIC, EOCENE.
    LATE 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.
    TEIST FM (INFORMAL)
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    61° 34' 14.09'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 13' 19.99'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6826753.59
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    458688.37
    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.
    875

  • Wellbore history
    General
    Well 34/4-6 was drilled in the northern part of the Snorre Field. The main objectives were to test the northern outline of the field and to confirm the oil/water-contact and reservoir characteristics of the Upper Lunde Formation. The stratigraphy and reservoir characteristics of the Middle and Lower Lunde together with the Lomvi Formations were secondary objectives. Prognosed depth was at 3236 m in Triassic rocks.
    Operations and results
    Appraisal well 34/4-6 was spudded with the semi-submersible installation Vinni on 31 December 1995 and drilled to TD at 3282 m in the Late Triassic Teist Formation. The 26" section was hampered by bad weather and large parts of the period from the evening of 9 January up to 18 January was spent as WOW. When reaching 740 m the bad weather also made it necessary to disconnect the riser from the well head. Technical problems when attempting to re-latch the pin connector back on to the well head resulted in the remaining section down to TD at 920 m in the 26" section being drilled with no returns to the surface. The well was drilled with spud mud down to 530 m, with gel mud from 530 m to 920 m, with gypsum/polymer mud from 920 m to 2345 m, and with gel mud from 2345 m to TD.
    Apart from the sandy Utsira Formation of Late - Middle Miocene to Pliocene age (1127.5 - 1239 m) and a sandstone unit within the Hordaland Group of Early Oligocene age (1358.5 - 1387 m), the upper section down to the Base Cretaceous Unconformity proved mainly claystones. No Jurassic rocks were encountered in the well. The Triassic Hegre Group consists of sandstones with minor shales and siltstones down to TD of the well. The target horizon, the Upper Lunde Formation, was encountered at 2576.5 m, 65 m deeper than prognosed. It had a gross thickness of 68.5 m with 39.7 m net sand. Hydrocarbons were encountered in the uppermost part of this formation with an OWC was at 2587 m, determined from RFT pressure points.
    The first appearance of shows was seen in the Shetland Group from ca 2090 m. This was seen in silt lenses where pale yellow fluorescence was accompanied by slow to moderate streaming blue white cut reaction. A slight yellow residue was occasionally observed. Entering the main reservoir at 2576.5 m, the shows were as follows in the interval 2576.5 - 2587 m (OWC): 100% yellow brown oil stain, 100% yellow fluorescence with instant to fast streaming blue white cut, leaving a light yellow brown residue upon evaporation. The odour was good. Below the OWC, shows decreased gradually to become extinct below 2624 m.
    Six cores were cut totalling 84.5 m. One core was cut in the Shetland Group crossing the border zone into Cromer Knoll Group. The other cores were taken in the Late Lunde Group where hydrocarbons were encountered in the uppermost section. The RFT chambers from this well gave no pressurized fluid samples. An atmospheric RFT sample from 2580 m contained ca 1.6 l oil and ca 2 l water/mud filtrate.
    The well was permanently abandoned on 27 March 1986 as an oil appraisal.
    Testing
    One DST test was performed in the well. This was a combined production/interference test in the Upper Lunde Formation. The well produced from the interval 2577 - 2585 m, with the interval 2592 - 2595 m as an observation interval. The test included three flow periods; 1) Clean-up flow of the lower zone; 2) initial flow of the upper zone; 3) main flow of the upper zone. The two first flows produced only cushion water. The last flow produced 1206 Sm2 oil /day with a wellhead pressure of 153.6 bar. The flowing bottom hole pressure was 359.6 bar at 2546.9 m. The gas-oil ratio was measured to 91.3 Sm3 /Sm3 after a four stage separation. The corresponding dead oil density was 824.5 kg/Sm3. Maximum temperature in the test was 99.7 deg C. During flow 3) wellhead samples and samples for recombination from the separator were taken. These samples include the "DST3" samples in the geochemical download report from IKU found further down on this fact page.

  • 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]
    530.00
    3207.00

  • 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
    2549.5
    2553.3
    [m ]
    2
    2576.0
    2583.0
    [m ]
    3
    2589.0
    2596.5
    [m ]
    4
    2600.0
    2612.9
    [m ]
    5
    2614.0
    2622.4
    [m ]
    6
    2642.0
    2660.5
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    58.1
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 2549-2553m
    Core photo at depth: 2576-2581m
    Core photo at depth: 2581-2583m
    Core photo at depth: 2589-2594m
    Core photo at depth: 2594-2596m
    2549-2553m
    2576-2581m
    2581-2583m
    2589-2594m
    2594-2596m
    Core photo at depth: 2600-2605m
    Core photo at depth: 2605-2610m
    Core photo at depth: 2610-2612m
    Core photo at depth: 2614-2619m
    Core photo at depth: 2619-2622m
    2600-2605m
    2605-2610m
    2610-2612m
    2614-2619m
    2619-2622m
    Core photo at depth: 2642-2647m
    Core photo at depth: 2647-2652m
    Core photo at depth: 2652-2657m
    Core photo at depth: 2657-2660m
    Core photo at depth:  
    2642-2647m
    2647-2652m
    2652-2657m
    2657-2660m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1853.0
    [m]
    SWC
    R.R.I
    1875.0
    [m]
    SWC
    R.R.I
    1900.0
    [m]
    SWC
    R.R.I
    1925.0
    [m]
    SWC
    R.R.I
    1960.0
    [m]
    SWC
    R.R.I
    2001.0
    [m]
    SWC
    R.R.I
    2025.0
    [m]
    SWC
    R.R.I
    2068.0
    [m]
    SWC
    R.R.I
    2130.0
    [m]
    SWC
    R.R.I
    2225.0
    [m]
    SWC
    R.R.I
    2267.0
    [m]
    SWC
    R.R.I
    2300.0
    [m]
    SWC
    R.R.I

  • 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
    0.00
    0.00
    OIL
    18.03.1986 - 00:00
    YES

  • Lithostratigraphy

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.39
    pdf
    2.36

  • 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
    1.65
    pdf
    8.39

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    2592
    2595
    6.4
    1.1
    2577
    2585
    12.7
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    93
    1.1
    93
    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
    1.1
    1173
    72726
    0.821
    0.770
    62

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL VDL GR
    750
    1841
    CBL VDL GR
    2780
    3255
    CST
    1853
    2762
    CST
    1853
    2762
    DLL MSFL GR SP
    2545
    2766
    GR
    0
    530
    ISF DDBHC GR
    521
    917
    ISF DDBHC GR
    904
    1853
    ISF LSS GR
    1841
    2769
    ISF LSS GR
    2761
    3281
    LDL CNL GR
    2761
    3282
    LDL CNL NGT GR
    1841
    2769
    LDL GR
    521
    919
    LDL GR
    904
    1854
    MWD
    521
    919
    MWD
    904
    1854
    MWD
    1841
    2770
    MWD
    2761
    3282
    RFT
    2578
    2747
    RFT
    2580
    2580
    RFT
    2583
    2585
    SHDT GR
    1841
    2770
    SHDT GR
    2761
    3282
    VELOCITY
    300
    3240

  • 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
    521.0
    36
    530.0
    0.00
    LOT
    SURF.COND.
    20
    904.0
    26
    920.0
    1.63
    LOT
    INTERM.
    13 3/8
    1841.0
    17 1/2
    1856.0
    1.80
    LOT
    INTERM.
    9 5/8
    2760.0
    12 1/4
    2770.0
    1.99
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    530
    1.06
    WATER BASED
    03.01.1986
    530
    1.06
    WATER BASED
    06.01.1986
    530
    1.06
    WATER BASED
    30.12.1985
    585
    1.07
    7.0
    16.3
    WATER BASED
    13.01.1986
    740
    1.14
    6.0
    13.5
    WATER BASED
    13.01.1986
    904
    1.10
    12.0
    7.2
    WATER BASED
    05.02.1986
    920
    1.10
    12.0
    7.2
    WATER BASED
    05.02.1986
    920
    1.12
    7.0
    13.9
    WATER BASED
    13.01.1986
    920
    1.14
    6.0
    12.5
    WATER BASED
    13.01.1986
    920
    1.12
    7.0
    14.4
    WATER BASED
    13.01.1986
    920
    1.14
    5.0
    9.6
    WATER BASED
    14.01.1986
    920
    1.15
    5.0
    10.1
    WATER BASED
    13.01.1986
    920
    1.15
    5.0
    10.6
    WATER BASED
    13.01.1986
    920
    1.14
    6.0
    11.1
    WATER BASED
    19.01.1986
    920
    1.14
    8.0
    11.5
    WATER BASED
    19.01.1986
    920
    1.14
    9.0
    10.6
    WATER BASED
    19.01.1986
    920
    1.03
    WATER BASED
    19.01.1986
    920
    1.14
    5.0
    12.0
    WATER BASED
    13.01.1986
    920
    1.15
    5.0
    10.1
    WATER BASED
    19.01.1986
    1110
    1.11
    19.0
    10.1
    WATER BASED
    05.02.1986
    1381
    1.13
    17.0
    9.1
    WATER BASED
    05.02.1986
    1791
    1.31
    20.0
    10.6
    WATER BASED
    05.02.1986
    1856
    1.48
    22.0
    8.7
    WATER BASED
    05.02.1986
    1856
    1.48
    24.0
    9.1
    WATER BASED
    05.02.1986
    1856
    1.48
    25.0
    9.6
    WATER BASED
    05.02.1986
    1856
    1.48
    25.0
    10.6
    WATER BASED
    05.02.1986
    1861
    1.48
    17.0
    9.6
    WATER BASED
    05.02.1986
    2127
    1.55
    19.0
    11.5
    WATER BASED
    05.02.1986
    2273
    1.65
    27.0
    12.0
    WATER BASED
    05.02.1986
    2345
    1.65
    21.0
    11.1
    WATER BASED
    11.02.1986
    2443
    1.68
    21.0
    10.1
    WATER BASED
    11.02.1986
    2495
    1.68
    16.0
    8.7
    WATER BASED
    11.02.1986
    2498
    1.68
    18.0
    9.6
    WATER BASED
    11.02.1986
    2549
    1.70
    19.0
    6.8
    WATER BASED
    11.02.1986
    2560
    1.70
    19.0
    6.3
    WATER BASED
    11.02.1986
    2575
    1.70
    22.0
    6.3
    WATER BASED
    12.02.1986
    2575
    1.70
    23.0
    7.2
    WATER BASED
    17.02.1986
    2576
    1.70
    22.0
    6.8
    WATER BASED
    11.02.1986
    2576
    1.70
    18.0
    6.8
    WATER BASED
    10.03.1986
    2576
    1.70
    18.0
    6.8
    WATER BASED
    17.03.1986
    2576
    1.70
    19.0
    6.8
    WATER BASED
    17.03.1986
    2576
    1.70
    17.0
    6.3
    WATER BASED
    24.03.1986
    2576
    1.70
    19.0
    6.8
    WATER BASED
    24.03.1986
    2576
    1.70
    19.0
    7.2
    WATER BASED
    24.03.1986
    2576
    1.70
    17.0
    6.3
    WATER BASED
    18.03.1986
    2576
    1.70
    18.0
    6.8
    WATER BASED
    24.03.1986
    2588
    1.70
    22.0
    6.3
    WATER BASED
    12.02.1986
    2600
    1.70
    23.0
    6.8
    WATER BASED
    12.02.1986
    2632
    1.70
    22.0
    6.8
    WATER BASED
    17.02.1986
    2660
    1.70
    22.0
    7.7
    WATER BASED
    17.02.1986
    2680
    1.70
    17.0
    7.7
    WATER BASED
    10.03.1986
    2700
    1.70
    18.0
    6.8
    WATER BASED
    10.03.1986
    2720
    1.70
    18.0
    6.3
    WATER BASED
    12.03.1986
    2720
    1.70
    18.0
    6.3
    WATER BASED
    08.03.1986
    2720
    1.70
    18.0
    6.3
    WATER BASED
    17.03.1986
    2746
    1.70
    20.0
    7.7
    WATER BASED
    17.02.1986
    2760
    1.62
    17.0
    6.8
    WATER BASED
    05.03.1986
    2760
    1.62
    21.0
    7.2
    WATER BASED
    28.02.1986
    2760
    1.62
    17.0
    7.7
    WATER BASED
    03.03.1986
    2760
    1.62
    18.0
    6.8
    WATER BASED
    03.03.1986
    2760
    1.62
    19.0
    7.7
    WATER BASED
    04.03.1986
    2770
    1.62
    43.0
    8.2
    WATER BASED
    26.02.1986
    2770
    1.70
    22.0
    7.7
    WATER BASED
    24.02.1986
    2770
    1.70
    27.0
    7.7
    WATER BASED
    24.02.1986
    2770
    1.70
    20.0
    7.7
    WATER BASED
    24.02.1986
    2770
    1.70
    22.0
    7.7
    WATER BASED
    24.02.1986
    2770
    1.62
    26.0
    6.8
    WATER BASED
    26.02.1986
    2792
    1.62
    19.0
    6.8
    WATER BASED
    28.02.1986
    3282
    1.62
    17.0
    6.8
    WATER BASED
    10.03.1986
    3282
    1.70
    18.0
    7.2
    WATER BASED
    10.03.1986

  • 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
    0.22