Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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11.11.2024 - 01:26
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34/7-22

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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.
    34/7-22
    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.
    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.
    34/7-22
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    SG 8431 RP -row 0279 & columm 0815
    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.
    766-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.
    48
    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,
    15.08.1993
    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.
    01.10.1993
    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.
    01.10.1995
    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.
    28.02.2008
    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.
    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.
    YES
    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.
    TARBERT 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.
    226.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2507.0
    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).
    2507.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    1.6
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    92
    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.
    DRAKE FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    61° 16' 42.37'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 10' 18.72'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6794244.54
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    455600.91
    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.
    2167

  • Wellbore history
    General
    Well 34/7-22 is located between the Gullfaks and Snorre fields on Tampen Spur in the Northern North Sea. The main objective was to prove hydrocarbons and reservoir quality of a Brent Group prospect named the STWB prospect, defined by structural closure towards east and north, dip closure towards south, combined with fault seal against the Main Tordis Fault (MTF) towards west. Sands within Paleocene, Cretaceous, and Late Jurassic were secondary objectives.
    Operations and results
    Wildcat well 34/7-22 was spudded with the semi-submersible installation West Delta on 15 August 1993 and drilled to TD at 2507 m in the Early Jurassic Drake Formation. Since possible shallow gas levels had been predicted, a 9 7/8" pilot hole was drilled. The Nordland Group consisted mainly of claystone except for the sandy Utsira Formation, which came in at 907 m. On the seismic, top Hordaland was interpreted to coincide with a structural high which was considered to be a clay diapir. The "clay diapir" consisted, however, almost entirely of sandstone which partly belongs to the Utsira Formation and the upper part of the Hordaland Group. The unexpected large amounts of sand caused operational problems due to instability and the drill string got stuck at 1086 m, on 17 August. The string was backed off and the well was re-spudded on 18 August. The casing program was re-designed to penetrate and stabilize the sandy Utsira Formation and Hordaland Group with a weighted mud system. After re-spud, drilling commenced as planned. The well was drilled with spud mud down to 1329 m, and with KCl mud with glycol from 1329 m to TD.
    No sand or hydrocarbons were found within the Paleocene and Cretaceous (Campanian) intervals, but at 2178.5 m, a water wet Intra-Draupne Formation sand was penetrated. At 2184 m the Heather Formation was encountered with a thickness of 40 m, 31m thicker than prognosed. Top reservoir, corresponding to Top Tarbert Formation, Brent Group, was encountered at 2224 m and was proven oil bearing down to 2249.5 m, with good to excellent reservoir quality as proven by cores, electrical logs and the test. FMT pressure points showed that the Tarbert Formation reservoir was in a separate pressure regime from the underlying Ness-Etive-Rannoch Formations, and also from the above Intra Draupne Sandstone.
    Apart from the live oil in the Tarbert Formation reservoir there were weak shows in claystones in the interval 2080 - 2176 in the Shetland Group. Similar shows were observed in the Late Jurassic Intra Draupne Formation sand and in the Heather Formation. Below the OWC in the Tarbert reservoir shows continued down to 2256 m. There were no shows below 2256 m.
    A total of 7 cores were cut in the interval 2226 - 2331.5 m in Tarbert and Ness Formations. Segregated samples of oil and gas were obtained at 2228.5 m and 2246.3 m in the Tarbert Formation.
    The well was permanently abandoned on 1 October 1993 as an oil discovery.
    Testing
    One well test was performed in the Tarbert Formation in the interval 2236 - 2242 m. In the final stage of the main flow period the well flowed 1154 Sm3 oil/day through a 14.3 mm choke. The oil had a GOR of 47 Sm3/Sm3, a dead oil density of 0.85 g/cm3 and the gas gravity was 0.695 (air = 1). The maximum recorded temperature in the test was 84.5 deg C.

  • 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]
    820.00
    2506.00

  • 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
    2226.0
    2234.3
    [m ]
    2
    2235.0
    2254.3
    [m ]
    3
    2255.0
    2271.4
    [m ]
    4
    2272.0
    2281.0
    [m ]
    5
    2284.0
    2289.0
    [m ]
    6
    2291.0
    2302.7
    [m ]
    7
    2303.0
    2331.5
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    98.2
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 2226-2231m
    Core photo at depth: 2231-2234m
    Core photo at depth: 2235-2240m
    Core photo at depth: 2240-2245m
    Core photo at depth: 2245-2250m
    2226-2231m
    2231-2234m
    2235-2240m
    2240-2245m
    2245-2250m
    Core photo at depth: 2250-2254m
    Core photo at depth: 2256-2260m
    Core photo at depth: 2260-2265m
    Core photo at depth: 2265-2270m
    Core photo at depth: 2270-2271m
    2250-2254m
    2256-2260m
    2260-2265m
    2265-2270m
    2270-2271m
    Core photo at depth: 2272-2277m
    Core photo at depth: 2277-2281m
    Core photo at depth: 2284-2289m
    Core photo at depth: 2291-2296m
    Core photo at depth: 2296-2301m
    2272-2277m
    2277-2281m
    2284-2289m
    2291-2296m
    2296-2301m
    Core photo at depth: 2301-2302m
    Core photo at depth: 2303-2308m
    Core photo at depth: 2308-2313m
    Core photo at depth: 2313-2318m
    Core photo at depth: 2318-2323m
    2301-2302m
    2303-2308m
    2308-2313m
    2313-2318m
    2318-2323m
    Core photo at depth: 2323-2328m
    Core photo at depth: 2328-2331m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    2323-2328m
    2328-2331m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    860.0
    [m]
    DC
    SPT
    900.0
    [m]
    DC
    SPT
    920.0
    [m]
    DC
    SPT
    940.0
    [m]
    DC
    SPT
    960.0
    [m]
    DC
    SPT
    980.0
    [m]
    DC
    SPT
    1000.0
    [m]
    DC
    SPT
    1020.0
    [m]
    DC
    SPT
    1040.0
    [m]
    DC
    SPT
    1060.0
    [m]
    DC
    SPT
    1080.0
    [m]
    DC
    SPT
    1100.0
    [m]
    DC
    SPT
    1120.0
    [m]
    DC
    SPT
    1140.0
    [m]
    DC
    SPT
    1160.0
    [m]
    DC
    SPT
    1180.0
    [m]
    DC
    SPT
    1200.0
    [m]
    DC
    SPT
    1220.0
    [m]
    DC
    SPT
    1240.0
    [m]
    DC
    SPT
    1260.0
    [m]
    DC
    SPT
    1280.0
    [m]
    DC
    SPT
    1300.0
    [m]
    DC
    SPT
    1320.0
    [m]
    DC
    SPT
    1340.0
    [m]
    DC
    SPT
    1370.0
    [m]
    DC
    SPT
    1390.0
    [m]
    DC
    SPT
    1430.0
    [m]
    DC
    SPT
    1450.0
    [m]
    DC
    SPT
    1470.0
    [m]
    DC
    SPT
    1490.0
    [m]
    DC
    SPT
    1510.0
    [m]
    DC
    SPT
    1530.0
    [m]
    DC
    SPT
    1550.0
    [m]
    DC
    SPT
    1580.0
    [m]
    DC
    SPT
    1600.0
    [m]
    DC
    SPT
    1620.0
    [m]
    DC
    SPT
    1640.0
    [m]
    DC
    SPT
    1650.0
    [m]
    DC
    SPT
    1660.0
    [m]
    DC
    SPT
    1690.0
    [m]
    DC
    SPT
    1730.0
    [m]
    DC
    SPT
    1750.0
    [m]
    DC
    SPT
    1770.0
    [m]
    DC
    SPT
    1790.0
    [m]
    DC
    SPT
    1800.0
    [m]
    DC
    SPT
    1840.0
    [m]
    DC
    SPT
    1860.0
    [m]
    DC
    SPT
    1880.0
    [m]
    DC
    SPT
    1920.0
    [m]
    DC
    SPT
    1940.0
    [m]
    DC
    SPT
    1960.0
    [m]
    DC
    SPT
    1980.0
    [m]
    DC
    SPT
    2000.0
    [m]
    DC
    SPT
    2020.0
    [m]
    DC
    SPT
    2060.0
    [m]
    DC
    SPT
    2080.0
    [m]
    DC
    SPT
    2100.0
    [m]
    DC
    SPT
    2120.0
    [m]
    DC
    SPT
    2140.0
    [m]
    DC
    SPT
    2160.0
    [m]
    DC
    SPT
    2175.0
    [m]
    DC
    SPT
    2180.0
    [m]
    DC
    SPT
    2184.0
    [m]
    DC
    SPT
    2187.0
    [m]
    DC
    SPT
    2190.0
    [m]
    DC
    SPT
    2195.0
    [m]
    DC
    SPT
    2204.0
    [m]
    DC
    SPT
    2225.0
    [m]
    DC
    SPT
    2264.0
    [m]
    C
    SPT
    2285.0
    [m]
    C
    SPT
    2297.0
    [m]
    C
    SPT
    2305.0
    [m]
    C
    SPT
    2326.0
    [m]
    C
    SPT
    2351.0
    [m]
    DC
    SPT
    2360.0
    [m]
    DC
    SPT
    2370.0
    [m]
    DC
    SPT
    2390.0
    [m]
    DC
    SPT
    2410.0
    [m]
    DC
    SPT
    2430.0
    [m]
    DC
    SPT
    2450.0
    [m]
    DC
    SPT
    2470.0
    [m]
    DC
    SPT
    2479.0
    [m]
    DC
    SPT
    2485.0
    [m]
    DC
    SPT
    2497.0
    [m]
    DC
    SPT
    2506.0
    [m]
    DC
    SPT

  • Lithostratigraphy

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.53
    pdf
    2.55
    pdf
    0.25

  • 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
    23.25

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    2236
    2242
    14.3
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    15.000
    33.000
    84
    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
    1154
    0.840
    0.690
    67

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBIL GR
    2102
    2465
    DIFL ACL ZDL GR
    1315
    2106
    DLL MLL GR
    2210
    2285
    DPIL MAC ZDL CN DSL
    2102
    2507
    FMT GR
    2179
    2323
    FMT GR
    2246
    2340
    HDIP GR
    2102
    2480
    MWD DPR - GR RES DIR
    255
    2507
    SWC GR
    1355
    2085
    SWC GR
    2145
    2490
    VELOCITY
    1100
    2490

  • 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
    352.0
    36
    352.0
    0.00
    LOT
    INTERM.
    18 5/8
    803.0
    26
    803.0
    1.62
    LOT
    INTERM.
    13 3/8
    1317.0
    17 1/2
    1317.0
    1.65
    LOT
    INTERM.
    9 5/8
    2102.0
    12 1/4
    2102.0
    1.93
    LOT
    LINER
    7
    2506.0
    8 1/2
    2506.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    302
    1.20
    WATER BASED
    20.08.1993
    358
    1.06
    10.0
    70.0
    WATER BASED
    23.08.1993
    358
    1.20
    11.5
    5.0
    WATER BASED
    20.08.1993
    588
    1.06
    11.0
    72.0
    WATER BASED
    23.08.1993
    591
    1.20
    4.0
    13.0
    WATER BASED
    16.08.1993
    766
    1.06
    11.0
    72.0
    WATER BASED
    23.08.1993
    812
    1.20
    6.0
    13.0
    WATER BASED
    24.08.1993
    812
    1.12
    13.5
    15.0
    WATER BASED
    25.08.1993
    812
    1.12
    14.0
    16.0
    WATER BASED
    26.08.1993
    1068
    1.20
    5.0
    14.0
    WATER BASED
    18.08.1993
    1086
    1.20
    4.0
    14.0
    WATER BASED
    19.08.1993
    1113
    1.16
    4.0
    22.0
    WATER BASED
    27.08.1993
    1329
    1.22
    6.0
    21.0
    WATER BASED
    01.09.1993
    1329
    1.20
    5.0
    24.0
    WATER BASED
    01.09.1993
    1332
    1.29
    27.5
    15.0
    DUMMY
    01.09.1993
    1657
    1.40
    24.0
    22.0
    DUMMY
    31.08.1993
    2049
    1.56
    34.0
    26.0
    DUMMY
    01.09.1993
    2112
    1.59
    61.0
    32.0
    DUMMY
    02.09.1993
    2117
    1.59
    34.0
    22.0
    DUMMY
    06.09.1993
    2117
    1.59
    35.0
    25.0
    DUMMY
    06.09.1993
    2117
    1.59
    34.0
    27.0
    DUMMY
    06.09.1993
    2226
    1.63
    32.0
    18.0
    DUMMY
    06.09.1993
    2255
    1.63
    32.0
    16.0
    DUMMY
    07.09.1993
    2284
    1.63
    33.0
    15.0
    DUMMY
    08.09.1993
    2303
    1.63
    34.0
    17.0
    DUMMY
    09.09.1993
    2345
    1.63
    35.0
    16.0
    DUMMY
    13.09.1993
    2507
    1.63
    34.0
    21.0
    DUMMY
    13.09.1993
    2507
    1.63
    34.0
    21.0
    DUMMY
    13.09.1993
    2507
    1.66
    35.0
    24.0
    DUMMY
    14.09.1993
    2507
    1.66
    40.0
    26.0
    DUMMY
    15.09.1993
    2507
    1.66
    53.0
    50.0
    DUMMY
    16.09.1993
    2507
    1.66
    48.0
    44.0
    DUMMY
    17.09.1993
    2507
    1.66
    38.0
    35.0
    DUMMY
    23.09.1993
    2507
    1.66
    38.0
    35.0
    DUMMY
    23.09.1993
    2507
    1.66
    38.0
    35.0
    DUMMY
    23.09.1993
    2507
    1.66
    65.0
    45.0
    DUMMY
    24.09.1993
    2507
    1.66
    38.0
    39.0
    DUMMY
    20.09.1993
    2507
    1.66
    44.0
    40.0
    DUMMY
    20.09.1993
    2507
    1.66
    43.0
    42.0
    DUMMY
    20.09.1993
    2507
    1.66
    39.0
    35.0
    DUMMY
    22.09.1993
    2507
    1.66
    36.0
    32.0
    DUMMY
    28.09.1993
    2507
    1.66
    39.0
    35.0
    DUMMY
    28.09.1993
    2507
    1.66
    39.0
    35.0
    DUMMY
    28.09.1993
    2507
    1.66
    35.0
    33.0
    DUMMY
    29.09.1993
    2507
    1.46
    24.0
    29.0
    DUMMY
    30.09.1993
    2507
    1.66
    35.0
    24.0
    DUMMY
    14.09.1994
    2507
    1.66
    40.0
    23.0
    DUMMY
    13.09.1993
    2507
    1.66
    38.0
    36.0
    DUMMY
    22.09.1993
    2507
    1.66
    38.0
    35.0
    DUMMY
    23.09.1993
    2507
    1.66
    65.0
    45.0
    DUMMY
    24.09.1993

  • 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
    0.21