Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
29.04.2024 - 01:33
Time of last synchronization with Norwegian Offshore Directorate's internal systems

25/8-5 S

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.
    25/8-5 S
    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.
    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.
    25/8-5
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    ESD-511 SP 162.93 / ESD-107 SP 198.56
    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.
    Esso Exploration and Production Norway 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.
    793-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.
    63
    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,
    21.07.1994
    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.
    22.09.1994
    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.
    22.09.1996
    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.
    29.08.2003
    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.
    PALEOCENE
    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.
    HEIMDAL FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    25.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    126.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3395.0
    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).
    2912.7
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    56.6
    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.
    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.
    SMITH BANK FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    59° 27' 27.1'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 21' 52.15'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6591324.83
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    463972.36
    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.
    2390

  • Wellbore history
    General
    The main objective of Well 25/8-5 S was to test the presence of hydrocarbons in both the lower Jurassic Statfjord Formation and in the Paleocene Heimdal Formation in the Elli Prospect. The well was to be drilled as a directional well in order to penetrate the two objectives.
    Operations and results
    Exploration well 25/8-5 S was spudded with the semi-submersible installation "Dyvi Stena" on 21 July 1994 and was drilled as a deviated well to a total depth of 3395 m (3040.7 m TVD RKB / 2887.7 m TVD SS), 57 m into late Triassic (Rhaetian) sediments of the Smith Bank Formation. The well was drilled vertical down to 1204 m before starting to build angle. It was drilled with seawater and hi-vis pills down to 1215 m and with KCl / polymer / PAC / Glycol from 1215 m to TD.
    Top Heimdal Formation was penetrated at 2112.6 m (2050 m TVD SS) at an inclination of 33 degrees and an azimuth of 171 degrees and was found to contain oil. The oil-water contact was estimated at 2158 m (2087 m TVD SS). The well found sands of the Vestland Group at 2836 m (2570 m TVD SS) water-wet and the second objective, Statfjord Formation at 3040 m (2687.3 m TVD SS) water-wet. The inclination at top Statfjord was 53.6 degrees and azimuth 163.5 degrees. Top Triassic was correlated to be at 3338 (2855.3 m TVD SS). The inclination was 55.2 degrees and azimuth 163.3 degrees at TD. The well was logged with LWD from 270 m to TD. The LWD included GR-Dual Resistivity and Compensated Density/Neutron. Wire line logs were run from 1170 m - 2291 m. Due to difficult hole conditions, it was not possible to run wire line logs below 2423 m. One core was cut in the Heimdal Formation from 2136 m to 2150 m and one core was cut in the Statfjord Formation from 3052 m to 3061 m. A FMT fluid sample was taken at 2133.6 (2067 m TVD SS) m in the Heimdal Formation. The well was suspended on 22 September as an oil discovery (Jotun). It was re-entered (25/8-5 S R) on 27 July 1997 for plugging and permanent abandonment. Permanent abandonment was completed on 3 August 1997.
    Testing
    The well was successfully tested in the Heimdal Formation, 2118 - 2149 m and flowed 1073 Sm3/day of 37° API oil through a 128/64 inch choke. The GOR was 38 Sm3/Sm3. No sand or water was produced.

  • 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]
    1180.00
    3395.00

  • 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
    2136.4
    2150.6
    [m ]
    2
    3052.0
    3061.2
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    23.4
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 2135-2140m
    Core photo at depth: 2140-2144m
    Core photo at depth: 2144-2148m
    Core photo at depth: 2148-2150m
    Core photo at depth: 3052-3057m
    2135-2140m
    2140-2144m
    2144-2148m
    2148-2150m
    3052-3057m
    Core photo at depth: 3057-3061m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    3057-3061m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1250.0
    [m]
    DC
    STRAT
    1800.0
    [m]
    DC
    STRAT
    1840.0
    [m]
    DC
    STRAT
    1880.0
    [m]
    DC
    STRAT
    1900.0
    [m]
    DC
    STRAT
    1921.0
    [m]
    DC
    STRAT
    1942.0
    [m]
    DC
    STRAT
    1954.0
    [m]
    DC
    STRAT
    1963.0
    [m]
    DC
    STRAT
    1984.0
    [m]
    DC
    STRAT
    1999.0
    [m]
    DC
    STRAT
    2023.0
    [m]
    DC
    STRAT
    2041.0
    [m]
    DC
    STRAT
    2050.0
    [m]
    DC
    STRAT
    2062.0
    [m]
    DC
    STRAT
    2089.0
    [m]
    DC
    STRAT
    2104.0
    [m]
    DC
    STRAT
    2128.0
    [m]
    SWC
    STRAT
    2134.0
    [m]
    DC
    STRAT
    2144.5
    [m]
    C
    STRAT
    2145.2
    [m]
    C
    STRAT
    2150.5
    [m]
    C
    STRAT
    2158.0
    [m]
    SWC
    STRAT
    2161.0
    [m]
    DC
    STRAT
    2167.5
    [m]
    SWC
    STRAT
    2183.0
    [m]
    DC
    STRAT
    2185.0
    [m]
    DC
    STRAT
    2224.0
    [m]
    DC
    STRAT
    2247.5
    [m]
    SWC
    STRAT
    2251.0
    [m]
    SWC
    STRAT
    2260.0
    [m]
    DC
    STRAT
    2299.0
    [m]
    DC
    STRAT
    2305.0
    [m]
    DC
    STRAT
    2314.0
    [m]
    DC
    STRAT
    2323.0
    [m]
    DC
    STRAT
    2350.0
    [m]
    DC
    STRAT
    2371.0
    [m]
    DC
    STRAT
    2389.0
    [m]
    DC
    STRAT
    2392.0
    [m]
    DC
    STRAT
    2398.0
    [m]
    DC
    STRAT
    2407.0
    [m]
    DC
    STRAT
    2428.0
    [m]
    DC
    STRAT
    2449.0
    [m]
    DC
    STRAT
    2485.0
    [m]
    DC
    STRAT
    2527.0
    [m]
    DC
    STRAT
    2554.0
    [m]
    DC
    STRAT
    2569.0
    [m]
    DC
    STRAT
    2602.0
    [m]
    DC
    STRAT
    2623.0
    [m]
    DC
    STRAT
    2647.0
    [m]
    DC
    STRAT
    2653.0
    [m]
    DC
    STRAT
    2662.0
    [m]
    DC
    STRAT
    2680.0
    [m]
    DC
    STRAT
    2701.0
    [m]
    DC
    STRAT
    2710.0
    [m]
    DC
    STRAT
    2737.0
    [m]
    DC
    STRAT
    2755.0
    [m]
    DC
    STRAT
    2761.0
    [m]
    DC
    STRAT
    2773.0
    [m]
    DC
    STRAT
    2785.0
    [m]
    DC
    STRAT
    2794.0
    [m]
    DC
    STRAT
    2797.0
    [m]
    DC
    STRAT
    2803.0
    [m]
    DC
    STRAT
    2809.0
    [m]
    DC
    STRAT
    2818.0
    [m]
    DC
    STRAT
    2824.0
    [m]
    DC
    STRAT
    2827.0
    [m]
    DC
    STRAT
    2833.0
    [m]
    DC
    STRAT
    2836.0
    [m]
    DC
    STRAT
    2845.0
    [m]
    DC
    STRAT
    2851.0
    [m]
    DC
    STRAT
    2860.0
    [m]
    DC
    STRAT
    2869.0
    [m]
    DC
    STRAT
    2878.0
    [m]
    DC
    STRAT
    2896.0
    [m]
    DC
    STRAT
    2911.0
    [m]
    DC
    STRAT
    2920.0
    [m]
    DC
    STRAT
    2926.0
    [m]
    DC
    STRAT
    2935.0
    [m]
    DC
    STRAT
    2956.0
    [m]
    DC
    STRAT
    2980.0
    [m]
    DC
    STRAT
    2995.0
    [m]
    DC
    STRAT
    3010.0
    [m]
    DC
    STRAT
    3028.0
    [m]
    DC
    STRAT
    3040.0
    [m]
    DC
    STRAT
    3046.0
    [m]
    DC
    STRAT
    3052.4
    [m]
    C
    STRAT
    3055.4
    [m]
    C
    STRAT
    3058.3
    [m]
    C
    STRAT
    3059.4
    [m]
    C
    STRAT
    3067.0
    [m]
    DC
    STRAT
    3115.0
    [m]
    DC
    STRAT
    3154.0
    [m]
    DC
    STRAT
    3172.0
    [m]
    DC
    STRAT
    3181.0
    [m]
    DC
    STRAT
    3229.0
    [m]
    DC
    STRAT
    3271.0
    [m]
    DC
    STRAT
    3286.0
    [m]
    DC
    STRAT
    3328.0
    [m]
    DC
    STRAT
    3343.0
    [m]
    DC
    STRAT
    3349.0
    [m]
    DC
    STRAT
    3358.0
    [m]
    DC
    STRAT
    3379.0
    [m]
    DC
    STRAT
    3395.0
    [m]
    DC
    STRAT

  • 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
    2149.00
    2118.00
    15.09.1994 - 07:45
    YES

  • Lithostratigraphy

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    1.47

  • 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
    35.79

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    2118
    2149
    50.0
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    29.000
    82
    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
    1073
    40774
    0.850
    38

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    BRIDGE PLUG
    2230
    2230
    CCL
    1900
    2233
    DAL GR CAL CHT
    2135
    2423
    DAL GR CMT.TOP
    1470
    2285
    DLL MLL TBRT CHT GR
    0
    1153
    FMT
    2113
    2208
    FMT
    2117
    2201
    FMT
    2171
    2171
    HEXDIP
    1153
    2204
    LWD CDN - DEN DEU
    2268
    3373
    LWD CDR - DRES
    1170
    3387
    MWD - GR DIR
    274
    3395
    SWC
    2008
    2251
    VSP - MLR
    500
    2290
    ZDL CN SL MAC CHT
    1153
    2301
    ZDL CN SL MAC CHT
    1153
    2260

  • 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
    272.0
    36
    272.0
    0.00
    LOT
    SURF.COND.
    13 3/8
    1153.0
    17 1/2
    1170.0
    0.00
    LOT
    INTERM.
    9 5/8
    2291.0
    12 1/4
    2302.0
    0.00
    LOT
    OPEN HOLE
    3395.0
    8 1/2
    3395.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    180
    1.02
    DUMMY
    352
    1.13
    DUMMY
    811
    1.13
    DUMMY
    1137
    1.50
    16.0
    DUMMY
    1170
    1.20
    28.0
    WATER BASED
    1331
    1.23
    32.0
    WATER BASED
    1755
    1.37
    48.0
    WATER BASED
    2008
    1.50
    42.0
    WATER BASED
    2064
    1.50
    18.0
    DUMMY
    2094
    1.50
    39.0
    WATER BASED
    2108
    1.50
    16.0
    DUMMY
    2136
    1.50
    38.0
    WATER BASED
    2150
    1.50
    33.0
    WATER BASED
    2234
    1.50
    34.0
    WATER BASED
    2261
    1.50
    34.0
    WATER BASED
    2300
    1.50
    31.0
    WATER BASED
    2301
    1.50
    32.0
    WATER BASED
    2335
    1.22
    19.0
    WATER BASED
    2485
    1.22
    25.0
    WATER BASED
    2615
    1.23
    22.0
    WATER BASED
    2700
    1.23
    30.0
    WATER BASED
    2712
    1.22
    28.0
    WATER BASED
    2758
    1.21
    30.0
    WATER BASED
    2879
    1.26
    31.0
    WATER BASED
    3015
    1.30
    29.0
    WATER BASED
    3015
    1.26
    27.0
    WATER BASED
    3061
    1.33
    25.0
    WATER BASED
    3395
    1.40
    28.0
    WATER BASED

  • Thin sections at the Norwegian Offshore Directorate
    Thin sections at the Norwegian Offshore Directorate
    Depth
    Unit
    2137.00
    [m ]
    2136.40
    [m ]
    2137.25
    [m ]
    2137.55
    [m ]
    2137.75
    [m ]
    2138.00
    [m ]
    2138.25
    [m ]
    2138.50
    [m ]
    2138.75
    [m ]
    2139.00
    [m ]
    2139.25
    [m ]
    2139.55
    [m ]
    2139.75
    [m ]
    2140.00
    [m ]
    2140.25
    [m ]
    2140.55
    [m ]
    2140.75
    [m ]
    2141.00
    [m ]
    2141.25
    [m ]
    2141.50
    [m ]
    2141.75
    [m ]
    2142.00
    [m ]
    2142.25
    [m ]
    2142.50
    [m ]
    2142.75
    [m ]
    2143.00
    [m ]
    2143.55
    [m ]
    2143.75
    [m ]
    2144.00
    [m ]
    2144.25
    [m ]
    2144.75
    [m ]
    2145.00
    [m ]
    2145.25
    [m ]
    2145.55
    [m ]
    2145.75
    [m ]
    2146.00
    [m ]
    2146.25
    [m ]
    2146.55
    [m ]
    2146.75
    [m ]
    2147.00
    [m ]
    2147.25
    [m ]
    2147.80
    [m ]
    2148.00
    [m ]
    2148.25
    [m ]
    2148.50
    [m ]
    2148.75
    [m ]
    2149.00
    [m ]
    2149.25
    [m ]
    2149.50
    [m ]
    2149.80
    [m ]
    2150.00
    [m ]
    2150.25
    [m ]
    3052.00
    [m ]
    3052.60
    [m ]
    3053.00
    [m ]
    3053.75
    [m ]
    3054.25
    [m ]
    3054.75
    [m ]
    3055.25
    [m ]
    3055.75
    [m ]
    3056.25
    [m ]
    3056.80
    [m ]
    3057.75
    [m ]
    3057.25
    [m ]
    3058.25
    [m ]
    3058.75
    [m ]
    3059.55
    [m ]
    3059.25
    [m ]
    3060.50
    [m ]
    3061.00
    [m ]

  • 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
    0.19