Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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22.11.2024 - 09:09
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6507/6-2

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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.
    6507/6-2
    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.
    NORWEGIAN SEA
    Well name
    Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    6507/6-2
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    B-08-83 SP 1235
    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.
    679-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.
    81
    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,
    27.04.1991
    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.
    16.07.1991
    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.
    16.07.1993
    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.
    18.12.2008
    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 SHOWS
    Discovery wellbore
    Indicator which tells if the wellbore made a new discovery. Legal values: YES, NO. Prior to press-release or other information regarding drilling results, the indicator will be “NO” as a default.
    NO
    1st level with HC, age
    Age of lithostratigraphic unit, 1st level, where hydrocarbons were encountered. Examples of legal values: CRETACEOUS, EARLY CRETACEOUS, LATE JURASSIC, EOCENE. See also Norwegian Offshore Directorate bulletins.
    LATE CRETACEOUS
    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.
    LYSING 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.
    315.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4354.0
    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).
    4343.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    10.7
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    140
    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.
    ÅRE FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    65° 44' 26.42'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    7° 41' 6.55'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7291819.83
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    439718.65
    UTM zone
    Universal Transverse Mercator zone. Examples of legal values: 31, 32, 33, 34.
    32
    NPDID wellbore
    Norwegian Offshore Directorate's unique id for the wellbore.
    1520

  • Wellbore history
    General
    Well 6507/6-2 was drilled in the north-western corner of the block on a rotated fault block on the Dønna Terrace, immediately northwest of the main fault zone separating the Dønna Terrace from the Nordland Ridge. The main objective of the well 6507/6-2 was to test the hydrocarbon potential in the Fangst Group and in the Tilje Formation. A secondary target was to test the reservoir properties and hydrocarbon potential of a Cretaceous dome shaped structure interpreted to be a potential Lysing Formation Equivalent. The source rock properties in the Spekk and Åre Formations would be tested by the well. The commitment was to drill at least 50 m into rocks of Triassic age; with planned TD at 4200 m. No shallow gas warnings were given for this well.
    Operations and results
    Wildcat well 6507/6-2 was spudded with the semi-submersible installation West Alpha on 27 April 1991and drilled to TD at 4345 m (4343 m TVD RKB) in Late Triassic sediments of the Åre Formation. Only minor problems occurred while drilling. The well was drilled with spud mud down to 1040 m, with KCl mud from 1040 m to 3413 m, and with Hi-Temp polymer mud from 3413 m to TD.
    The well mainly penetrated claystones with minor silt and sandstone intervals down to Top Cromer Knoll Group at 2663 m. In the Cromer Knoll Group the lithology was mainly claystone with thin intervals of sandstone and limestone. The reservoir in the Fangst Group was reached at 3727 m, 336 m deeper than prognosed and proved to be dry. However, oil was found in a thin sand bed in the Lange Formation (Turonian age) at 2754 - 2757 m. This sand was neither cored nor production tested, but oil was recovered by RFT sampling.
    Sporadic shows were recorded in thin sandstone stringers at several levels in the Lange Formation (2745 to 2753 m, 2885 m, 2945 - 2955 m, and 2946 m). The well encountered a 102 m thick Spekk Formation sequence at 3174 m. The Spekk Formation had excellent hydrocarbon potential with TOC in the range 6 - 8%, and Hydrogen Index in the range 320 to 475 mg HC/g TOC. The highest HI was in the uppermost part of the formation. Shale samples from the Åre Formation had limited source rock potential with TOC around 2.4 % and HI around 100 mg/g HC.
    Two conventional cores were cut in the Garn Formation between 3727 to 3740 m. A total of 180 sidewall cores were attempted and 130 were recovered. After having evaluated the wire line logs, it was decided to take fluid samples at 2754.5 and 2886.5 m in the Lange Formation. A segregated sample was taken at 2754.5 m where 178 litre gas, 890 ml oil, and 100 ml water was recovered. Density of the dead oil (stock tank conditions) was 0.8322 g/cm3. It was not possible to get a sample at 2886.5 m.
    The well was permanently abandoned on 16 July 1991 as a well with oil shows.
    Testing
    No drill stem test was performed.

  • 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]
    1060.00
    4354.00

  • 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
    3727.0
    3732.2
    [m ]
    2
    3732.2
    3739.2
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    12.2
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 3727-3732m
    Core photo at depth: 3732-3732m
    Core photo at depth: 3732-3737m
    Core photo at depth: 3737-3739m
    Core photo at depth:  
    3727-3732m
    3732-3732m
    3732-3737m
    3737-3739m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1070.0
    [m]
    SWC
    SAGA
    1090.0
    [m]
    DC
    SAGA
    1110.0
    [m]
    DC
    SAGA
    1130.0
    [m]
    DC
    SAGA
    1150.0
    [m]
    DC
    SAGA
    1170.0
    [m]
    SWC
    SAGA
    1190.0
    [m]
    DC
    SAGA
    1210.0
    [m]
    DC
    SAGA
    1230.0
    [m]
    DC
    SAGA
    1250.0
    [m]
    DC
    SAGA
    1270.0
    [m]
    SWC
    SAGA
    1290.0
    [m]
    DC
    SAGA
    1310.0
    [m]
    DC
    SAGA
    1330.0
    [m]
    DC
    SAGA
    1370.0
    [m]
    SWC
    SAGA
    1390.0
    [m]
    DC
    SAGA
    1410.0
    [m]
    DC
    STRAT
    1430.0
    [m]
    DC
    STRAT
    1450.0
    [m]
    DC
    SAGA
    1470.0
    [m]
    SWC
    SAGA
    1490.0
    [m]
    DC
    STRAT
    1510.0
    [m]
    DC
    STRAT
    1530.0
    [m]
    DC
    SAGA
    1550.0
    [m]
    SWC
    SAGA
    1570.0
    [m]
    DC
    SAGA
    1590.0
    [m]
    DC
    SAGA
    1610.0
    [m]
    DC
    SAGA
    1620.0
    [m]
    SWC
    SAGA
    1640.0
    [m]
    DC
    SAGA
    1650.0
    [m]
    SWC
    SAGA
    1670.0
    [m]
    DC
    STRAT
    1680.0
    [m]
    SWC
    SAGA
    1700.0
    [m]
    DC
    SAGA
    1720.0
    [m]
    DC
    SAGA
    1740.0
    [m]
    DC
    STRAT
    1760.0
    [m]
    DC
    SAGA
    1770.0
    [m]
    SWC
    SAGA
    1790.0
    [m]
    DC
    STRAT
    1810.0
    [m]
    DC
    STRAT
    1830.0
    [m]
    DC
    SAGA
    1850.0
    [m]
    DC
    SAGA
    1890.0
    [m]
    DC
    SAGA
    1930.0
    [m]
    DC
    SAGA
    1950.0
    [m]
    DC
    SAGA
    2000.0
    [m]
    DC
    SAGA
    2020.0
    [m]
    DC
    SAGA
    2033.0
    [m]
    SWC
    SAGA
    2094.0
    [m]
    SWC
    STRAT
    2110.0
    [m]
    DC
    STRAT
    2116.0
    [m]
    SWC
    STRAT
    2130.0
    [m]
    DC
    STRAT
    2144.0
    [m]
    SWC
    STRAT
    2150.0
    [m]
    DC
    STRAT
    2160.0
    [m]
    DC
    STRAT
    2170.0
    [m]
    DC
    STRAT
    2180.0
    [m]
    DC
    STRAT
    2190.0
    [m]
    DC
    STRAT
    2200.0
    [m]
    DC
    STRAT
    2210.0
    [m]
    DC
    STRAT
    2220.0
    [m]
    DC
    STRAT
    2230.0
    [m]
    DC
    STRAT
    2240.0
    [m]
    DC
    STRAT
    2250.0
    [m]
    DC
    STRAT
    2260.0
    [m]
    DC
    STRAT
    2280.0
    [m]
    DC
    STRAT
    2290.0
    [m]
    DC
    STRAT
    2300.0
    [m]
    DC
    STRAT
    2310.0
    [m]
    DC
    STRAT
    2320.0
    [m]
    DC
    STRAT
    2330.0
    [m]
    DC
    STRAT
    2340.0
    [m]
    DC
    STRAT
    2350.0
    [m]
    DC
    STRAT
    2360.0
    [m]
    DC
    STRAT
    2370.0
    [m]
    DC
    STRAT
    2380.0
    [m]
    DC
    STRAT
    2390.0
    [m]
    DC
    STRAT
    2400.0
    [m]
    DC
    STRAT
    2410.0
    [m]
    DC
    STRAT
    2420.0
    [m]
    DC
    STRAT
    2430.0
    [m]
    DC
    STRAT
    2440.0
    [m]
    DC
    STRAT
    2450.0
    [m]
    DC
    STRAT
    2460.0
    [m]
    DC
    STRAT
    2470.0
    [m]
    DC
    STRAT
    2480.0
    [m]
    DC
    STRAT
    2490.0
    [m]
    DC
    STRAT
    2500.0
    [m]
    DC
    STRAT
    2510.0
    [m]
    DC
    STRAT
    2520.0
    [m]
    DC
    STRAT
    2530.0
    [m]
    DC
    STRAT
    2540.0
    [m]
    DC
    STRAT
    2550.0
    [m]
    DC
    STRAT
    2560.0
    [m]
    DC
    STRAT
    2570.0
    [m]
    DC
    STRAT
    2580.0
    [m]
    DC
    STRAT
    2590.0
    [m]
    DC
    STRAT
    2610.0
    [m]
    DC
    STRAT
    2620.0
    [m]
    DC
    STRAT
    2630.0
    [m]
    DC
    STRAT
    2640.0
    [m]
    DC
    STRAT
    2650.0
    [m]
    DC
    STRAT
    2654.0
    [m]
    SWC
    STRAT
    2670.0
    [m]
    DC
    STRAT
    2680.0
    [m]
    DC
    STRAT
    2690.0
    [m]
    DC
    STRAT
    2700.0
    [m]
    DC
    STRAT
    2710.0
    [m]
    DC
    STRAT
    2720.0
    [m]
    DC
    STRAT
    2730.0
    [m]
    DC
    STRAT
    2740.0
    [m]
    DC
    STRAT
    2752.0
    [m]
    SWC
    STRAT
    2760.0
    [m]
    DC
    STRAT
    2770.0
    [m]
    DC
    STRAT
    2780.0
    [m]
    DC
    STRAT
    2790.0
    [m]
    DC
    STRAT
    2800.0
    [m]
    DC
    STRAT
    2810.0
    [m]
    DC
    STRAT
    2820.0
    [m]
    DC
    STRAT
    2825.0
    [m]
    SWC
    STRAT
    2830.0
    [m]
    DC
    STRAT
    2840.0
    [m]
    DC
    STRAT
    2850.0
    [m]
    DC
    STRAT
    2860.0
    [m]
    DC
    STRAT
    2870.0
    [m]
    DC
    STRAT
    2875.0
    [m]
    SWC
    STRAT
    2880.0
    [m]
    DC
    STRAT
    2890.0
    [m]
    DC
    STRAT
    2900.0
    [m]
    DC
    STRAT
    2915.0
    [m]
    DC
    STRAT
    2930.0
    [m]
    DC
    STRAT
    2940.0
    [m]
    DC
    STRAT
    2950.0
    [m]
    DC
    STRAT
    2960.0
    [m]
    DC
    STRAT
    2972.0
    [m]
    SWC
    STRAT
    2980.0
    [m]
    DC
    STRAT
    2990.0
    [m]
    DC
    STRAT
    3000.0
    [m]
    DC
    STRAT
    3010.0
    [m]
    DC
    STRAT
    3020.0
    [m]
    DC
    STRAT
    3030.0
    [m]
    DC
    STRAT
    3090.0
    [m]
    DC
    STRAT
    3100.0
    [m]
    DC
    STRAT
    3107.5
    [m]
    SWC
    STRAT
    3120.0
    [m]
    DC
    STRAT
    3130.0
    [m]
    DC
    STRAT
    3140.0
    [m]
    SWC
    STRAT
    3150.0
    [m]
    DC
    STRAT
    3160.0
    [m]
    DC
    STRAT
    3167.0
    [m]
    SWC
    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
    RFT
    RFT-2A
    2754.50
    2886.50
    08.06.1991 - 00:00
    YES

  • Lithostratigraphy

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.34
    pdf
    3.26

  • 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
    17.86

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL VDL
    1875
    3308
    CBL VDL GR
    800
    2026
    DIL MSFL SLS GR AMS
    3307
    4287
    DIL SLS GR
    4202
    4343
    DIL SLS LDL CNL GR
    2027
    3323
    DIL SLS LDL GR
    1038
    2044
    LDL CNL GR
    3307
    4260
    MWD - GR RES DIR
    411
    4354
    RFT
    2054
    2886
    RFT AMS GR
    3728
    3968
    SHDT GR
    3307
    4277
    VSP
    1000
    4270

  • 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
    405.0
    36
    406.0
    0.00
    LOT
    INTERM.
    20
    1040.0
    26
    1042.0
    1.69
    LOT
    INTERM.
    13 3/8
    2029.0
    17 1/2
    2030.0
    1.67
    LOT
    INTERM.
    9 5/8
    3309.0
    12 1/4
    3310.0
    1.99
    LOT
    OPEN HOLE
    3325.0
    8 1/2
    3326.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    336
    1.05
    WATER BASED
    30.04.1991
    336
    1.05
    WATER BASED
    30.04.1991
    336
    1.05
    WATER BASED
    02.05.1991
    336
    1.05
    WATER BASED
    03.05.1991
    336
    1.05
    WATER BASED
    03.05.1991
    336
    1.05
    WATER BASED
    03.05.1991
    336
    1.05
    WATER BASED
    03.05.1991
    336
    1.05
    WATER BASED
    03.05.1991
    336
    1.05
    WATER BASED
    03.05.1991
    730
    1.44
    16.0
    7.0
    WATER BASED
    16.07.1991
    1055
    1.05
    WATER BASED
    06.05.1991
    1055
    1.05
    WATER BASED
    06.05.1991
    1055
    1.05
    WATER BASED
    06.05.1991
    1350
    1.32
    16.0
    17.0
    WATER BASED
    13.05.1991
    1487
    1.35
    16.0
    18.0
    WATER BASED
    13.05.1991
    1848
    1.45
    36.0
    25.0
    WATER BASED
    13.05.1991
    1906
    1.44
    13.0
    11.0
    WATER BASED
    16.07.1991
    2050
    1.55
    21.0
    24.0
    WATER BASED
    14.05.1991
    2050
    1.55
    20.0
    20.0
    WATER BASED
    22.05.1991
    2050
    1.55
    20.0
    18.0
    WATER BASED
    14.05.1991
    2050
    1.55
    21.0
    24.0
    WATER BASED
    14.05.1991
    2050
    1.55
    20.0
    20.0
    WATER BASED
    15.05.1991
    2050
    1.55
    20.0
    17.0
    WATER BASED
    16.05.1991
    2050
    1.55
    14.0
    21.0
    WATER BASED
    21.05.1991
    2056
    1.55
    20.0
    17.0
    WATER BASED
    22.05.1991
    2285
    1.52
    22.0
    14.0
    WATER BASED
    22.05.1991
    2285
    1.55
    22.0
    16.0
    WATER BASED
    22.05.1991
    2295
    1.52
    22.0
    16.0
    WATER BASED
    22.05.1991
    2396
    1.52
    20.0
    19.0
    WATER BASED
    23.05.1991
    2531
    1.52
    14.0
    16.0
    WATER BASED
    24.05.1991
    2531
    1.52
    15.0
    16.0
    WATER BASED
    27.05.1991
    2531
    1.52
    15.0
    16.0
    WATER BASED
    28.05.1991
    2548
    1.52
    15.0
    14.0
    WATER BASED
    28.05.1991
    2548
    1.52
    15.0
    14.0
    WATER BASED
    30.05.1991
    2573
    1.52
    16.0
    15.0
    WATER BASED
    30.05.1991
    2573
    1.52
    16.0
    15.0
    WATER BASED
    28.05.1991
    2694
    1.52
    15.0
    16.0
    WATER BASED
    28.05.1991
    2694
    1.52
    15.0
    16.0
    WATER BASED
    30.05.1991
    2727
    1.53
    22.0
    15.0
    WATER BASED
    30.05.1991
    2815
    1.52
    19.0
    15.0
    WATER BASED
    30.05.1991
    2907
    1.52
    19.0
    16.0
    WATER BASED
    30.05.1991
    2907
    1.54
    18.0
    15.0
    WATER BASED
    04.06.1991
    2907
    1.54
    17.0
    18.0
    WATER BASED
    03.06.1991
    2994
    1.54
    19.0
    16.0
    WATER BASED
    04.06.1991
    3013
    1.54
    21.0
    17.0
    WATER BASED
    04.06.1991
    3111
    1.54
    20.0
    17.0
    WATER BASED
    05.06.1991
    3169
    1.54
    21.0
    16.0
    WATER BASED
    07.06.1991
    3217
    1.55
    20.0
    18.0
    WATER BASED
    07.06.1991
    3314
    1.55
    22.0
    16.0
    WATER BASED
    07.06.1991
    3325
    1.55
    22.0
    14.0
    WATER BASED
    11.06.1991
    3325
    1.55
    21.0
    16.0
    WATER BASED
    11.06.1991
    3325
    1.55
    21.0
    16.0
    WATER BASED
    11.06.1991
    3325
    1.52
    20.0
    16.0
    WATER BASED
    11.06.1991
    3327
    1.52
    21.0
    18.0
    WATER BASED
    13.06.1991
    3327
    1.52
    21.0
    18.0
    WATER BASED
    13.06.1991
    3413
    1.52
    19.0
    13.0
    WATER BASED
    17.06.1991
    3460
    1.52
    21.0
    28.0
    WATER BASED
    18.06.1991
    3503
    1.52
    20.0
    10.0
    WATER BASED
    18.06.1991
    3618
    1.52
    21.0
    12.0
    WATER BASED
    18.06.1991
    3722
    1.45
    14.0
    12.0
    WATER BASED
    15.07.1991
    3727
    1.52
    20.0
    10.0
    WATER BASED
    21.06.1991
    3727
    1.52
    20.0
    10.0
    WATER BASED
    19.06.1991
    3732
    1.52
    21.0
    12.0
    WATER BASED
    21.06.1991
    3740
    1.52
    20.0
    10.0
    WATER BASED
    21.06.1991
    3806
    1.52
    22.0
    13.0
    WATER BASED
    21.06.1991
    3849
    1.52
    21.0
    12.0
    WATER BASED
    25.06.1991
    4002
    1.50
    21.0
    12.0
    WATER BASED
    25.06.1991
    4056
    1.48
    17.0
    10.0
    WATER BASED
    25.06.1991
    4100
    1.45
    18.0
    13.0
    WATER BASED
    25.06.1991
    4180
    1.45
    18.0
    13.0
    WATER BASED
    26.06.1991
    4180
    1.45
    15.0
    13.0
    WATER BASED
    28.06.1991
    4273
    1.45
    18.0
    15.0
    WATER BASED
    01.07.1991
    4284
    1.45
    18.0
    14.0
    WATER BASED
    02.07.1991
    4284
    1.45
    18.0
    14.0
    WATER BASED
    02.07.1991
    4296
    1.45
    17.0
    14.0
    WATER BASED
    02.07.1991
    4327
    1.45
    15.0
    15.0
    WATER BASED
    03.07.1991
    4335
    1.45
    15.0
    18.0
    WATER BASED
    03.07.1991
    4343
    1.45
    16.0
    15.0
    WATER BASED
    05.07.1991
    4354
    1.45
    15.0
    23.0
    WATER BASED
    08.07.1991
    4354
    1.45
    14.0
    9.0
    WATER BASED
    09.07.1991
    4354
    1.45
    16.0
    19.0
    WATER BASED
    09.07.1991
    4354
    1.45
    15.0
    23.0
    WATER BASED
    09.07.1991
    4354
    1.45
    15.0
    23.0
    WATER BASED
    09.07.1991
    4354
    1.45
    17.0
    20.0
    WATER BASED
    11.07.1991
    4354
    1.45
    17.0
    20.0
    WATER BASED
    15.07.1991

  • 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
    0.29