Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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sodir.no          Norsk
05.11.2024 - 01:27
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31/4-7

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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.
    31/4-7
    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.
    31/4-7
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    954 - 447 SP. 600
    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.
    Norsk Hydro Produksjon AS
    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.
    425-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,
    26.07.1984
    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.
    11.09.1984
    Release date
    Date when raw data which has been reported to the authorities from the wellbore is not confidential any longer. Normally 2 years after finishing the drilling. May be earlier if the area of the production license is relinquished.
    11.09.1986
    Publication date
    Date quality control of the wellbore information was completed, so it can be published on the internet as a 'Well Data Summary Sheet' wellbore with more information available than other wellbores.
    01.04.2014
    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/GAS
    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.
    FENSFJORD FM
    2nd level with HC, age
    Age of lithostratigraphic unit, 2nd level, where hydrocarbons were encountered. Examples of legal values: CRETACEOUS, EARLY CRETACEOUS, LATE JURASSIC, EOCENE.
    EARLY JURASSIC
    2nd level with HC, formation
    Name of lithostartigraphic unit, 2nd 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.
    STATFJORD GP
    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.
    136.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2505.0
    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).
    2504.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    2.5
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    106
    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.
    STATFJORD GP
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    60° 34' 8.21'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    3° 1' 5.82'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6714934.67
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    501002.29
    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.
    235

  • Wellbore history
    General
    Well 31/4-7 was drilled on the southernmost part of the Brage Horst, close to the junction between the Brage/Oseberg fault and the Troll Fault. The primary objective was to test the hydrocarbon potential and the internal stratigraphy on the Brage Horst compartment on the western flank of the Brage Field. Neighbouring well 31/4-2 to the north on the Brage Horst found live oil in two thin sandstones in the Brent Group, while wells 31/4-3, 4, and 5 on the main Brage structure on the Bjørgvin Arch had proved oil in the "Intra-Heather Sandstone Unit II" (Fensfjord Formation). The well was planned to be drilled 50 m into the Statfjord Group at 2765 +/- 50 m.
    Operations and results
    Wildcat well 31/4-7 was spudded with the semi-submersible installation Vildkat Explorer on 26 July 1984 and drilled to TD at 2505 m in Late Triassic sediments of the Statfjord Group. No significant problem was encountered in the operations. The well was drilled with gel/spud mud down to 1000 m, with KCl/polymer mud from 1000 m to 1816 m, and with a NaCl/polymer mud from 1816 m to TD.
    The well encountered hydrocarbon bearing sandstones and siltstones in the Fensfjord Formation and in the Statfjord Group sandstones. The Fensfjord Formation was poorly developed with sandstones grading to siltstones followed by siltstones. It was found gas bearing over the interval 2026 - 2056 m with a calculated net pay of 8 m, an average porosity of 20.5% and an average water saturation of 45%. The Statfjord Group came in at 2384 m and was found oil bearing down to the OWC at 2406 m. It consisted of fine to coarse sandstones. The net pay was calculated to be 12.5 m with a calculated average porosity of 22.2% and an average water saturation of 42.3%.
    Five cores were cut in the well, starting at 2045 m in the Fensfjord Formation and stopping at 2150.5 m in Dunlin Group shales. Several attempts were made to obtain a segregated RFT sample in the Fensfjord Formation without success. Oil and gas was recovered in a segregated RFT sample at 2395.7 m in the Statfjord Group.
    The well was permanently abandoned on 11 September 1986.
    Testing
    Two drill stem tests were carried out.
    DST 1 tested the interval 2389.9 - 2397.9 m in the Statfjord Formation. It produced 700 Sm3 /day oil and 25000 Sm3 gas /day through a 40/64" choke. The GOR was 36 Sm3/Sm3, the oil density was 0.83 g/cm3 and the gas gravity 0.775 (air = 1) with 2.5 % CO2 and no H2S. Maximum bottom hole temperature at reference depth 2356.5 m was 101.7 deg C.
    DST 2 tested the interval 2028.5 - 2039.5 m in the Fensfjord Formation. It produced 26900 Sm3 /day gas with a water cut of 25% through a 36/64" choke. The test also produced some condensate. The gas gravity was 0.77 (air = 1) with trace CO2 and no H2S and the condensate gravity was 57.1 deg API. Maximum bottom hole temperature at reference depth 1991.8 m was 81.1 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]
    250.00
    2502.00

  • 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
    2045.0
    2063.0
    [m ]
    2
    2064.0
    2082.0
    [m ]
    3
    2083.0
    2111.0
    [m ]
    4
    2111.0
    2135.0
    [m ]
    5
    2139.0
    2150.0
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    99.0
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 2045-2049m
    Core photo at depth: 2049-2053m
    Core photo at depth: 2053-2057m
    Core photo at depth: 2057-2061m
    Core photo at depth: 2061-2063m
    2045-2049m
    2049-2053m
    2053-2057m
    2057-2061m
    2061-2063m
    Core photo at depth: 2064-2067m
    Core photo at depth: 2068-2072m
    Core photo at depth: 2072-2076m
    Core photo at depth: 2076-2080m
    Core photo at depth: 2080-2082m
    2064-2067m
    2068-2072m
    2072-2076m
    2076-2080m
    2080-2082m
    Core photo at depth: 2083-2087m
    Core photo at depth: 2091-2095m
    Core photo at depth: 2095-2099m
    Core photo at depth: 2099-2103m
    Core photo at depth: 2103-2107m
    2083-2087m
    2091-2095m
    2095-2099m
    2099-2103m
    2103-2107m
    Core photo at depth: 2107-2111m
    Core photo at depth: 2114-2118m
    Core photo at depth: 2118-2122m
    Core photo at depth: 2122-2126m
    Core photo at depth: 2126-2130m
    2107-2111m
    2114-2118m
    2118-2122m
    2122-2126m
    2126-2130m
    Core photo at depth: 2130-2134m
    Core photo at depth: 2134-2138m
    Core photo at depth: 2138-2142m
    Core photo at depth: 2142-2145m
    Core photo at depth: 2146-2150m
    2130-2134m
    2134-2138m
    2138-2142m
    2142-2145m
    2146-2150m
    Core photo at depth: 2150-2150m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    2150-2150m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1950.0
    [m]
    SWC
    HYDRO
    1960.0
    [m]
    SWC
    HYDRO
    1970.0
    [m]
    C
    HYDRO
    1975.0
    [m]
    SWC
    HYDRO
    1986.0
    [m]
    SWC
    HYDRO
    1993.0
    [m]
    SWC
    HYDRO
    1995.0
    [m]
    SWC
    HYDRO
    2000.0
    [m]
    SWC
    HYDRO
    2010.0
    [m]
    SWC
    HYDRO
    2020.0
    [m]
    SWC
    HYDRO
    2025.0
    [m]
    SWC
    HYDRO
    2027.0
    [m]
    SWC
    HYDRO
    2030.0
    [m]
    SWC
    HYDRO
    2030.0
    [m]
    C
    HYDRO
    2037.0
    [m]
    C
    HYDRO
    2038.0
    [m]
    SWC
    HYDRO
    2041.0
    [m]
    SWC
    HYDRO
    2045.0
    [m]
    C
    HYDRO
    2045.0
    [m]
    SWC
    HYDRO
    2048.0
    [m]
    C
    HYDRO
    2051.0
    [m]
    C
    HYDRO
    2055.0
    [m]
    C
    HYDRO
    2063.8
    [m]
    C
    HYDRO
    2065.0
    [m]
    C
    HYDRO
    2070.0
    [m]
    C
    HYDRO
    2075.0
    [m]
    C
    HYDRO
    2080.0
    [m]
    C
    HYDRO
    2085.0
    [m]
    C
    HYDRO
    2090.0
    [m]
    C
    HYDRO
    2096.0
    [m]
    SWC
    HYDRO
    2102.0
    [m]
    SWC
    HYDRO
    2105.0
    [m]
    C
    HYDRO
    2107.0
    [m]
    C
    HYDRO
    2109.0
    [m]
    C
    HYDRO
    2110.0
    [m]
    SWC
    HYDRO
    2110.6
    [m]
    C
    HYDRO
    2115.0
    [m]
    C
    HYDRO
    2123.0
    [m]
    C
    HYDRO
    2130.0
    [m]
    C
    HYDRO
    2130.0
    [m]
    SWC
    HYDRO
    2135.0
    [m]
    C
    HYDRO
    2138.0
    [m]
    SWC
    HYDRO
    2140.0
    [m]
    C
    HYDRO
    2150.0
    [m]
    SWC
    HYDRO
    2160.0
    [m]
    DC
    HYDRO
    2170.0
    [m]
    DC
    HYDRO
    2180.0
    [m]
    DC
    HYDRO
    2190.0
    [m]
    DC
    HYDRO
    2200.0
    [m]
    DC
    HYDRO
    2211.0
    [m]
    SWC
    HYDRO
    2220.0
    [m]
    DC
    HYDRO
    2230.0
    [m]
    DC
    HYDRO
    2240.0
    [m]
    DC
    HYDRO
    2245.0
    [m]
    SWC
    HYDRO
    2250.0
    [m]
    SWC
    HYDRO
    2260.0
    [m]
    DC
    HYDRO
    2275.0
    [m]
    SWC
    HYDRO
    2289.0
    [m]
    SWC
    HYDRO
    2296.0
    [m]
    SWC
    HYDRO
    2308.0
    [m]
    SWC
    HYDRO
    2315.0
    [m]
    DC
    HYDRO
    2325.0
    [m]
    SWC
    HYDRO
    2330.0
    [m]
    SWC
    HYDRO
    2340.0
    [m]
    DC
    HYDRO
    2350.0
    [m]
    SWC
    HYDRO
    2360.0
    [m]
    DC
    HYDRO
    2365.0
    [m]
    SWC
    HYDRO
    2375.0
    [m]
    SWC
    HYDRO
    2383.0
    [m]
    SWC
    HYDRO
    2393.0
    [m]
    SWC
    HYDRO
    2396.0
    [m]
    SWC
    HYDRO
    2400.0
    [m]
    SWC
    HYDRO
    2406.0
    [m]
    SWC
    HYDRO
    2415.0
    [m]
    SWC
    HYDRO
    2420.0
    [m]
    SWC
    HYDRO
    2430.0
    [m]
    DC
    HYDRO
    2440.0
    [m]
    DC
    HYDRO
    2453.0
    [m]
    SWC
    HYDRO
    2460.0
    [m]
    DC
    HYDRO
    2470.0
    [m]
    DC
    HYDRO
    2475.0
    [m]
    SWC
    HYDRO
    2480.0
    [m]
    DC
    HYDRO
    2490.0
    [m]
    DC
    HYDRO
    2500.0
    [m]
    DC
    HYDRO

  • 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
    2398.00
    2390.00
    31.08.1984 - 00:00
    YES
    DST
    DST2
    2039.00
    2028.00
    CONDENSATE
    06.09.1984 - 00:00
    YES

  • Lithostratigraphy

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.30
    pdf
    14.53

  • 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
    14.63

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    2390
    2398
    15.9
    2.0
    2029
    2040
    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
    2.0
    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
    684
    25000
    0.830
    0.775
    37
    2.0
    26900
    0.770

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    BHC GR
    2000
    2080
    CBL VDL
    500
    1800
    DLL MSFL GR
    1799
    2143
    DLL MSFL GR
    2300
    2501
    ISF LSS GR SP
    247
    1793
    ISF LSS GR SP
    2147
    2503
    ISF LSS GR SP MSFL
    1799
    2147
    LDT CNL GR
    2120
    2504
    LDT CNL GR NGT
    1799
    2148
    LDT GR
    983
    1794
    RFT
    2030
    2120
    RFT
    2030
    2490
    RFT
    2395
    2395
    SHDT
    1925
    2505
    VSP
    600
    2505

  • 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
    247.0
    36
    248.0
    0.00
    LOT
    SURF.COND.
    20
    984.0
    26
    1000.0
    1.80
    LOT
    INTERM.
    13 3/8
    1801.0
    17 1/2
    1816.0
    1.82
    LOT
    INTERM.
    9 5/8
    2499.0
    12 1/4
    2505.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    205
    1.18
    WATER BASED
    11.09.1984
    247
    1.20
    28.0
    19.0
    WATER BASED
    30.07.1984
    1000
    1.04
    WATER BASED
    01.08.1984
    1000
    1.02
    WATER BASED
    30.07.1984
    1000
    1.04
    WATER BASED
    01.08.1984
    1000
    1.08
    WATER BASED
    01.08.1984
    1000
    1.04
    40.0
    24.0
    WATER BASED
    30.07.1984
    1000
    1.02
    WATER BASED
    30.07.1984
    1000
    1.08
    WATER BASED
    01.08.1984
    1124
    1.15
    15.0
    14.0
    WATER BASED
    06.08.1984
    1367
    1.24
    16.0
    22.0
    WATER BASED
    06.08.1984
    1671
    1.36
    18.0
    20.0
    WATER BASED
    06.08.1984
    1816
    1.40
    18.0
    22.0
    WATER BASED
    06.08.1984
    1816
    1.40
    WATER BASED
    07.08.1984
    1816
    1.40
    36.0
    15.0
    WATER BASED
    08.08.1984
    1816
    1.40
    WATER BASED
    09.08.1984
    1816
    1.29
    16.5
    30.0
    WATER BASED
    13.08.1984
    1816
    1.40
    WATER BASED
    07.08.1984
    1816
    1.29
    16.5
    30.0
    WATER BASED
    13.08.1984
    1816
    1.40
    36.0
    15.0
    WATER BASED
    08.08.1984
    1816
    1.40
    WATER BASED
    09.08.1984
    2045
    1.30
    11.0
    10.0
    WATER BASED
    13.08.1984
    2064
    1.30
    11.0
    13.0
    WATER BASED
    13.08.1984
    2096
    1.29
    12.0
    16.0
    WATER BASED
    13.08.1984
    2139
    1.30
    WATER BASED
    15.08.1984
    2139
    1.29
    26.0
    12.0
    WATER BASED
    14.08.1984
    2139
    1.30
    WATER BASED
    15.08.1984
    2151
    1.30
    25.0
    13.0
    WATER BASED
    16.08.1984
    2241
    1.31
    24.0
    13.0
    WATER BASED
    21.08.1984
    2369
    1.31
    25.0
    10.0
    WATER BASED
    21.08.1984
    2490
    1.32
    26.0
    16.0
    WATER BASED
    21.08.1984
    2505
    1.33
    24.0
    16.0
    WATER BASED
    21.08.1984
    2505
    1.33
    28.0
    17.0
    WATER BASED
    22.08.1984
    2505
    1.33
    25.0
    14.0
    WATER BASED
    24.08.1984
    2505
    1.27
    26.0
    13.0
    WATER BASED
    27.08.1984
    2505
    1.15
    18.0
    11.0
    WATER BASED
    27.08.1984
    2505
    1.15
    18.0
    13.0
    WATER BASED
    27.08.1984
    2505
    1.33
    28.0
    14.0
    WATER BASED
    23.08.1984
    2505
    1.33
    25.0
    14.0
    WATER BASED
    24.08.1984
    2505
    1.15
    18.0
    13.0
    WATER BASED
    27.08.1984
    2505
    1.33
    28.0
    17.0
    WATER BASED
    22.08.1984
    2505
    1.33
    28.0
    14.0
    WATER BASED
    23.08.1984
    2505
    1.27
    26.0
    13.0
    WATER BASED
    27.08.1984
    2505
    1.15
    18.0
    11.0
    WATER BASED
    27.08.1984

  • Pressure plots
    Pressure plots
    The pore pressure data is sourced from well logs if no other source is specified. In some wells where pore pressure logs do not exist, information from Drill stem tests and kicks have been used. The data has been reported to the NPD, and further processed and quality controlled by IHS Markit.
    Pressure plots
    Document name
    Document format
    Document size [MB]
    pdf
    0.23