Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
27.12.2024 - 01:25
Time of last synchronization with Norwegian Offshore Directorate's internal systems

34/7-19

Export: PDF icon PDF

  • General information
    General information
    Attribute Value
    Wellbore name
    Official name of wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    34/7-19
    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.
    SUSPENDED
    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.
    34/7-19
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    GE-83: RAD 237 & KOLONNE 1037
    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.
    698-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.
    95
    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,
    24.09.1991
    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.
    27.12.1991
    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.
    27.12.1993
    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.
    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.
    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.
    18.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    285.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2800.0
    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).
    2800.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    2.7
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    91
    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.
    COOK FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    61° 23' 38.96'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 5' 31.46'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6807191.07
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    451502.27
    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.
    1838

  • Wellbore history
    General
    Well 34/7-19 is an appraisal well on the Vigdis Middle structure, south of the Snorre Field on Tampen Spur in the Northern North Sea. The well was drilled approximately 1.5 km north-west of well 34/7-16, on a north-west dipping, rotated fault block. A wedge of partially eroded Viking Group/Heather Formation was interpreted above the reservoir. The primary objectives of the well were to prove the north-western extension of the 34/7-16 reservoir into Segment M1 of the Vigdis Middle and establish an oil water contact for the upper Brent Group. A secondary objective was to test the possible existence of a Late Jurassic Draupne Formation shale wedge. The well was designed to be used in possible future field development. Shallow gas was expected at a depth of 445 m on the well location. This level represents a sand layer at Top Pliocene where gas had been observed in several previous wells in block 34/7. Shallow gas could also be expected in thin sand layers, below seismic resolution down to Top Utsira Formation. A boulder bed could be expected approximately 60 m below sub seabed. Prognosed TD was estimated to 2803 m, and an OWC was assumed at 2418 m (2400 m MSL).
    Operations and results
    Well 34/7-19 was spudded with the semi-submersible installation West Alpha on 24 September 1991 and drilled to TD at 2800 m in the Early Jurassic Cook Formation. At core point, 2439 m the weather deteriorated. Due to extreme heave the top drive jumped out of hook. The drill pipe bent and the top drive fell down on the drill floor. The shear ram was activated leaving the drill string with core assembly in the hole. Fishing and WOW caused 4.5 days delay before coring could commence. The well was drilled with spud mud down to 1166 m and with KCl mud from 1166 m to TD. Shallow gas was not encountered in this well, but a zone from 526 to 527.5 m was interpreted as potentially gas bearing. One boulder bed was encountered at 363 m.
    Down to the Top Jurassic at 2455.5 the well penetrated mainly claystones. An exception to this was the sandy Utsira Formation from 944 to 1065 m. The Jurassic interval comprised the Late Jurassic Heather Formation, the Middle Jurassic Brent Group and the Early Jurassic Dunlin Group.
    Well 34/7-19 encountered oil in the Tarbert Formation of the Brent Group. The resistivity logs indicated oil down to 2477 m and water up to 2483 m. The OWC was from the RFT-pressure measurements estimated at 2478 m (2460 mSS). An RFT sample recovered oil at 2465 m. The oil bearing part of the Tarbert Formation (2455.5 - 2478.0 m) had an estimated average log porosity of 0.26, a net to gross ratio of 0.8 and an average water saturation of 39 %. The total Tarbert Formation (2455.5 - 2499.5 m) had an estimated average porosity of 0.25 and a net to gross ratio of 0.67.
    Sparse oil shows were observed in sandstone lamina and claystones of the Rogaland Group in parts of the interval 1688 -1750 m. Shows were observed in silty and sandy lithologies in the interval 2180 -2300 in the Kyrre Formation. Over the Brent Group reservoir good oil shows were encountered in cores from 2454 - 2482 m. Below 2482 the amount of shows decreased, and below 2486 hydrocarbon shows were not observed.
    Ten cores were cut in the interval 2439 - 2661 m, giving full core coverage of the Brent Group. A total of 16.5 m in the Cromer Knoll Group/Heather Formation, 202.5 m in the Brent Group and 3 m of the Dunlin Group was cored. The total core recovery was 211.8 m (95.4 %). One RFT segregated fluid sample was taken at 2465 m. The 2 3/4 gallon chamber recovered 10.3 l water and filtrate with only small amounts of oil and gas (0.2 l and 7 l, respectively). The content of the 1 gallon chamber had a similar composition.
    The well was suspended 27 December 1991 as a possible future development well. It is classified as an oil appraisal.
    Testing
    Two drill stem tests were performed in this well.
    DST 1 perforated and tested the interval 2542 to 2557 m in the water bearing Etive Formation. The maximum stable production rate during main flow was 466 Sm3 water/day. Initial reservoir pressure and temperature, at sensor depth (2487.7 m), was measured to 369.2 bar and 86 deg C.
    DST 2 perforated and tested the interval 2455.3 to 2468.3 m in the oil bearing part of the Tarbert Formation. Maximum stable production rate was 1070 fluid Sm3/day through a 14.3 mm choke. The produced fluid was oil with a GOR of 42 Sm3/Sm3. The oil density was 0.835 g/cm3 and the gas gravity was 0.700 (air = 1). Initial pressure and temperature, at sensor depth (2414.2 m), was measured to 361.8 bar and 83 deg C, 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]
    1170.00
    2800.00

  • 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
    2439.0
    2447.7
    [m ]
    2
    2451.0
    2478.8
    [m ]
    3
    2479.0
    2503.0
    [m ]
    4
    2503.0
    2508.7
    [m ]
    5
    2509.0
    2529.6
    [m ]
    6
    2530.0
    2557.3
    [m ]
    7
    2558.0
    2576.3
    [m ]
    8
    2577.0
    2604.0
    [m ]
    9
    2605.0
    2632.9
    [m ]
    10
    2633.0
    2659.4
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    213.7
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 2439-2443m
    Core photo at depth: 2443-2447m
    Core photo at depth: 2447-2448m
    Core photo at depth: 2451-2455m
    Core photo at depth: 2455-2459m
    2439-2443m
    2443-2447m
    2447-2448m
    2451-2455m
    2455-2459m
    Core photo at depth: 2459-2463m
    Core photo at depth: 2463-2467m
    Core photo at depth: 2467-2471m
    Core photo at depth: 2471-2475m
    Core photo at depth: 2475-2478m
    2459-2463m
    2463-2467m
    2467-2471m
    2471-2475m
    2475-2478m
    Core photo at depth: 2479-2483m
    Core photo at depth: 2483-2487m
    Core photo at depth: 2487-2491m
    Core photo at depth: 2491-2495m
    Core photo at depth: 2495-2499m
    2479-2483m
    2483-2487m
    2487-2491m
    2491-2495m
    2495-2499m
    Core photo at depth: 2499-2503m
    Core photo at depth: 2503-2507m
    Core photo at depth: 2507-2508m
    Core photo at depth: 2509-2513m
    Core photo at depth: 2513-2517m
    2499-2503m
    2503-2507m
    2507-2508m
    2509-2513m
    2513-2517m
    Core photo at depth: 2517-2521m
    Core photo at depth: 2521-2525m
    Core photo at depth: 2525-2529m
    Core photo at depth: 2529-2530m
    Core photo at depth: 2530-2534m
    2517-2521m
    2521-2525m
    2525-2529m
    2529-2530m
    2530-2534m
    Core photo at depth: 2534-2538m
    Core photo at depth: 2538-2542m
    Core photo at depth: 2542-2546m
    Core photo at depth: 2546-2550m
    Core photo at depth: 2550-2554m
    2534-2538m
    2538-2542m
    2542-2546m
    2546-2550m
    2550-2554m
    Core photo at depth: 2554-2557m
    Core photo at depth: 2558-2562m
    Core photo at depth: 2562-2566m
    Core photo at depth: 2566-2570m
    Core photo at depth: 2570-2574m
    2554-2557m
    2558-2562m
    2562-2566m
    2566-2570m
    2570-2574m
    Core photo at depth: 2574-2575m
    Core photo at depth: 2577-2581m
    Core photo at depth: 2581-2585m
    Core photo at depth: 2585-2589m
    Core photo at depth: 2589-2593m
    2574-2575m
    2577-2581m
    2581-2585m
    2585-2589m
    2589-2593m
    Core photo at depth: 2593-2597m
    Core photo at depth: 2597-2601m
    Core photo at depth: 2601-2604m
    Core photo at depth: 2605-2609m
    Core photo at depth: 2609-2613m
    2593-2597m
    2597-2601m
    2601-2604m
    2605-2609m
    2609-2613m
    Core photo at depth: 2613-2617m
    Core photo at depth: 2617-2621m
    Core photo at depth: 2621-2625m
    Core photo at depth: 2625-2629m
    Core photo at depth: 2629-2632m
    2613-2617m
    2617-2621m
    2621-2625m
    2625-2629m
    2629-2632m
    Core photo at depth: 2633-2637m
    Core photo at depth: 2637-2641m
    Core photo at depth: 2641-2645m
    Core photo at depth: 2645-2649m
    Core photo at depth: 2649-2653m
    2633-2637m
    2637-2641m
    2641-2645m
    2645-2649m
    2649-2653m
    Core photo at depth: 2653-2657m
    Core photo at depth: 2657-2659m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    2653-2657m
    2657-2659m

  • 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
    TEST2
    2455.30
    2468.30
    10.12.1991 - 00:15
    YES

  • Lithostratigraphy

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.44
    pdf
    1.07

  • 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
    20.46

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    2455
    2468
    14.3
    2.0
    2542
    2557
    6.4
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    13.000
    36.000
    83
    2.0
    13.000
    37.000
    86
    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
    1070
    0.835
    40
    2.0
    290

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    DLL LSS MSFL LDL GR AMS SP
    1152
    1940
    DSI DLL MSFL GR AMS SP
    1935
    2793
    DSI GR
    2400
    2715
    FMS LDL CNL NGL AMS
    1935
    2793
    MWD - CDN GR RES DIR TEMP
    2431
    2535
    MWD - GR RES DIR TEMP
    303
    2800
    RFT GR AMS
    2456
    2614
    VSP
    1090
    1970
    VSP
    1780
    2670

  • 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
    401.0
    36
    401.0
    0.00
    LOT
    INTERM.
    20
    1151.0
    26
    1166.0
    1.70
    LOT
    INTERM.
    13 3/8
    1935.0
    17 1/2
    1960.0
    1.77
    LOT
    INTERM.
    9 5/8
    2784.0
    12 1/4
    2800.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    402
    1.05
    WATER BASED
    25.09.1991
    402
    1.05
    WATER BASED
    26.09.1991
    420
    1.05
    WATER BASED
    30.09.1991
    686
    1.05
    WATER BASED
    01.10.1991
    1166
    1.05
    WATER BASED
    01.10.1991
    1166
    1.05
    WATER BASED
    01.10.1991
    1166
    1.20
    WATER BASED
    01.10.1991
    1166
    1.20
    WATER BASED
    03.10.1991
    1166
    1.25
    18.0
    16.0
    WATER BASED
    03.10.1991
    1166
    1.25
    19.0
    16.0
    WATER BASED
    08.10.1991
    1166
    1.35
    20.0
    17.0
    WATER BASED
    08.10.1991
    1166
    1.35
    20.0
    17.0
    WATER BASED
    08.10.1991
    1166
    1.35
    20.0
    17.0
    WATER BASED
    09.10.1991
    1166
    1.35
    20.0
    17.0
    WATER BASED
    09.10.1991
    1166
    1.25
    19.0
    16.0
    WATER BASED
    09.10.1991
    1166
    1.35
    20.0
    17.0
    WATER BASED
    09.10.1991
    1166
    1.25
    19.0
    16.0
    WATER BASED
    09.10.1991
    1166
    1.35
    20.0
    17.0
    WATER BASED
    09.10.1991
    1166
    1.25
    19.0
    16.0
    WATER BASED
    10.10.1991
    1166
    1.35
    20.0
    17.0
    WATER BASED
    10.10.1991
    1166
    1.35
    20.0
    17.0
    WATER BASED
    10.10.1991
    1402
    1.40
    32.0
    23.0
    WATER BASED
    10.10.1991
    1402
    1.40
    32.0
    23.0
    WATER BASED
    09.10.1991
    1402
    1.40
    32.0
    23.0
    WATER BASED
    09.10.1991
    1402
    1.40
    32.0
    23.0
    WATER BASED
    08.10.1991
    1554
    1.40
    33.0
    24.0
    WATER BASED
    09.10.1991
    1554
    1.40
    33.0
    24.0
    WATER BASED
    09.10.1991
    1554
    1.40
    33.0
    24.0
    WATER BASED
    10.10.1991
    1767
    1.45
    34.0
    22.0
    WATER BASED
    10.10.1991
    1767
    1.45
    34.0
    22.0
    WATER BASED
    09.10.1991
    1960
    1.52
    25.0
    15.0
    WATER BASED
    11.10.1991
    1960
    1.50
    30.0
    15.0
    WATER BASED
    11.10.1991
    1960
    1.52
    20.0
    13.0
    WATER BASED
    14.10.1991
    1960
    1.52
    21.0
    14.0
    WATER BASED
    14.10.1991
    1960
    1.52
    23.0
    15.0
    WATER BASED
    14.10.1991
    2160
    1.60
    36.0
    24.0
    WATER BASED
    15.10.1991
    2303
    1.62
    34.0
    25.0
    WATER BASED
    17.10.1991
    2439
    1.64
    35.0
    24.0
    WATER BASED
    17.10.1991
    2439
    1.64
    38.0
    25.0
    WATER BASED
    21.10.1991
    2439
    1.64
    38.0
    25.0
    WATER BASED
    21.10.1991
    2439
    1.64
    46.0
    24.0
    WATER BASED
    24.10.1991
    2439
    1.64
    46.0
    25.0
    WATER BASED
    28.10.1991
    2439
    1.64
    38.0
    25.0
    WATER BASED
    18.10.1991
    2439
    1.64
    38.0
    25.0
    WATER BASED
    21.10.1991
    2439
    1.64
    38.0
    25.0
    WATER BASED
    22.10.1991
    2439
    1.64
    38.0
    25.0
    WATER BASED
    23.10.1991
    2449
    1.64
    31.0
    14.0
    WATER BASED
    28.10.1991
    2451
    1.64
    30.0
    15.0
    WATER BASED
    28.10.1991
    2485
    1.64
    29.0
    15.0
    WATER BASED
    28.10.1991
    2508
    1.64
    30.0
    16.0
    WATER BASED
    29.10.1991
    2558
    1.64
    33.0
    20.0
    WATER BASED
    31.10.1991
    2558
    1.64
    30.0
    16.0
    WATER BASED
    04.11.1991
    2558
    1.64
    30.0
    15.0
    WATER BASED
    05.11.1991
    2558
    1.64
    30.0
    15.0
    WATER BASED
    05.11.1991
    2558
    1.64
    32.0
    18.0
    WATER BASED
    05.11.1991
    2577
    1.64
    32.0
    19.0
    WATER BASED
    05.11.1991
    2605
    1.64
    28.0
    16.0
    WATER BASED
    06.11.1991
    2633
    1.64
    28.0
    14.0
    WATER BASED
    07.11.1991
    2661
    1.64
    33.0
    15.0
    WATER BASED
    08.11.1991
    2724
    1.64
    29.0
    15.0
    WATER BASED
    11.11.1991
    2794
    1.64
    28.0
    15.0
    WATER BASED
    11.11.1991
    2800
    1.64
    30.0
    15.0
    WATER BASED
    11.11.1991
    2800
    1.64
    30.0
    15.0
    WATER BASED
    13.11.1991
    2800
    1.64
    30.0
    15.0
    WATER BASED
    14.11.1991
    2800
    1.64
    21.0
    22.0
    WATER BASED
    18.11.1991
    2800
    1.64
    21.0
    22.0
    WATER BASED
    19.11.1991
    2800
    1.64
    27.0
    22.0
    WATER BASED
    19.11.1991
    2800
    1.64
    33.0
    24.0
    WATER BASED
    19.11.1991
    2800
    1.64
    33.0
    24.0
    WATER BASED
    20.11.1991
    2800
    1.64
    33.0
    24.0
    WATER BASED
    21.11.1991
    2800
    1.64
    34.0
    24.0
    WATER BASED
    25.11.1991
    2800
    1.64
    35.0
    24.0
    WATER BASED
    25.11.1991
    2800
    1.64
    34.0
    20.0
    WATER BASED
    26.11.1991
    2800
    1.64
    34.0
    20.0
    WATER BASED
    28.11.1991
    2800
    1.64
    28.0
    22.0
    WATER BASED
    28.11.1991
    2800
    1.64
    29.0
    21.0
    WATER BASED
    29.11.1991
    2800
    1.64
    28.0
    19.0
    WATER BASED
    03.12.1991
    2800
    1.64
    31.0
    21.0
    WATER BASED
    03.12.1991
    2800
    1.64
    31.0
    21.0
    WATER BASED
    03.12.1991
    2800
    1.64
    27.0
    20.0
    WATER BASED
    04.12.1991
    2800
    1.64
    27.0
    20.0
    WATER BASED
    05.12.1991
    2800
    1.64
    29.0
    26.0
    WATER BASED
    09.12.1991
    2800
    1.64
    29.0
    26.0
    WATER BASED
    09.12.1991
    2800
    1.64
    28.0
    30.0
    WATER BASED
    09.12.1991
    2800
    1.64
    29.0
    26.0
    WATER BASED
    11.12.1991
    2800
    1.64
    29.0
    26.0
    WATER BASED
    11.12.1991
    2800
    1.64
    29.0
    26.0
    WATER BASED
    12.12.1991
    2800
    1.64
    24.0
    26.0
    WATER BASED
    16.12.1991
    2800
    1.64
    29.0
    26.0
    WATER BASED
    16.12.1991
    2800
    1.64
    29.0
    26.0
    WATER BASED
    16.12.1991
    2800
    1.64
    29.0
    26.0
    WATER BASED
    16.12.1991
    2800
    1.64
    24.0
    26.0
    WATER BASED
    17.12.1991
    2800
    1.64
    29.0
    26.0
    WATER BASED
    17.12.1991
    2800
    1.64
    29.0
    26.0
    WATER BASED
    17.12.1991
    2800
    1.64
    19.0
    16.0
    WATER BASED
    14.11.1991
    2800
    1.64
    33.0
    24.0
    WATER BASED
    19.11.1991
    2800
    1.64
    34.0
    24.0
    WATER BASED
    22.11.1991
    2800
    1.64
    34.0
    20.0
    WATER BASED
    25.11.1991
    2800
    1.64
    29.0
    19.0
    WATER BASED
    03.12.1991
    2800
    1.64
    27.0
    20.0
    WATER BASED
    06.12.1991
    2800
    1.64
    29.0
    26.0
    WATER BASED
    17.12.1991

  • 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