Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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6506/12-10 A

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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.
    6506/12-10 A
    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.
    NORWEGIAN 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.
    6506/12-10
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    ST 8801- INLINE SP 920 & CROSSLINE SP 94
    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.
    Den norske stats oljeselskap 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.
    817-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.
    168
    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,
    27.06.1995
    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.
    11.12.1995
    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.
    11.12.1997
    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.
    24.09.2002
    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/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.
    FANGST GP
    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.
    BÅT GP
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    24.0
    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).
    6260.0
    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).
    5361.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    57.7
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    189
    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.
    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° 8' 7.82'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    6° 49' 6.47'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7225505.52
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    397658.22
    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.
    2610
  • Wellbore history

    General
    The main objective of well 6506/12-10 A was to appraise the down flanks hydrocarbons in the Garn, Ile, Tilje, and the Åre Formation, on the Smørbukk Field.
    Operations and results
    The appraisal sidetrack well 6506/12-10 A was kicked off with the semi-submersible installation "Ross Rig" from 2823 m in 6506/12-10 on 25 June 1995 and drilled to 6260 m with a total cost considerably higher than planned budget. The higher costs were mainly due to kick off and orienting problems from the vertical well, lots of trips to change bits, milling cones lost in the 12 1/4" hole and problems cementing the 7" liner. In general the drilling rate was lower than expected. Oil based mud (ANCO VERT) was used trough out the sidetrack. High mud weight (1.80 g/cm3) was used in the beginning to prevent formation damage during drilling. This can have caused lower ROP than expected. Prior to testing, a lot of leakage problems occurred within the test string mainly due to bad quality of the o-rings in the Halliburton test-valves. The string was pulled and reran 5 times before all the problems were sorted out. Total lost times in the test phase was 893 hrs (squeeze cementing of 7" liner, leak in BHA of the test string, BOP problems, WOW, fishing of packer slips).
    Eleven cores were cut in the Tilje and Åre Formations. Two FMT samples were taken in the Garn Formation (4397.7 m TVD and 4402.7 m TVD, respectively) and one in the Tilje Formation (4806.8 m TVD). The Garn samples contained water while the Tilje sample contained oil. The 6506/12-10A well proved producible oil in the Garn, Ile, Tilje and upper parts of the Åre Formations in good sand intervals. After testing the well 6506/12-10 A was permanently plugged and abandoned on 11 December 1995 as an oil and gas appraisal well.
    Testing
    The test plan included short tests of the Åre and Tilje Formations followed by a long term production period. Thereafter a minifrac from the rig plus a massive stimulation job of the Tilje Formation should be performed. The objectives for this operations was to try to establish the productivity improvements from a massive stimulation, and thereby more accurate be able to evaluate the production potential for the Tilje Formation within the Smørbukk field. Due to problems during cementing of the 7" liner, severe zone isolation problems occurred and the Åre test was abandoned for the more important Tilje test. The production test of well 6506/12-10 A perforated the interval 5686 m to 5706 m (4793 m to 4813 m TVD RKB) in the Tilje Formation. The Tilje test started, but it became more or less obvious during the test that it was the Åre formation that was producing 90 -100 % of the fluid and Tilje only contributed with a very small amount of fluid. Later analysis of test results, PVT analysis, comparison of FMT data from earlier wells and this well, confirm that it was the Åre formation that was produced during the test, and that the cement bound between the Åre and Tilje was broken down during the test. At the end of the test a minifrac was performed in the perforated interval to indicate stress level in the Tilje formation. The test was ended after two shiploads of oil were sent to Mongstad, and within the time budget.
  • 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]
    2800.00
    6260.00
  • 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
    5674.0
    5711.5
    [m ]
    2
    5711.5
    5748.4
    [m ]
    3
    5948.0
    5948.5
    [m ]
    4
    5959.0
    5971.2
    [m ]
    5
    5972.0
    5984.7
    [m ]
    6
    5986.0
    6005.0
    [m ]
    7
    6038.0
    6057.0
    [m ]
    8
    6057.0
    6060.7
    [m ]
    9
    6119.0
    6128.6
    [m ]
    10
    6160.0
    6178.0
    [m ]
    11
    6223.0
    6230.5
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    176.4
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES
  • Core photos

    Core photos
    Core photo at depth: 5674-5679m
    Core photo at depth: 5679-5684m
    Core photo at depth: 5684-5689m
    Core photo at depth: 5689-5694m
    Core photo at depth: 5694-5699m
    5674-5679m
    5679-5684m
    5684-5689m
    5689-5694m
    5694-5699m
    Core photo at depth: 5699-5704m
    Core photo at depth: 5704-5709m
    Core photo at depth: 5709-5712m
    Core photo at depth: 5712-5716m
    Core photo at depth: 5716-5721m
    5699-5704m
    5704-5709m
    5709-5712m
    5712-5716m
    5716-5721m
    Core photo at depth: 5721-5726m
    Core photo at depth: 5721-5731m
    Core photo at depth: 5731-5736m
    Core photo at depth: 5736-5741m
    Core photo at depth: 5741-5746m
    5721-5726m
    5721-5731m
    5731-5736m
    5736-5741m
    5741-5746m
    Core photo at depth: 5746-5748m
    Core photo at depth: 5948-5949m
    Core photo at depth: 5959-5964m
    Core photo at depth: 5964-5969m
    Core photo at depth: 5969-5971m
    5746-5748m
    5948-5949m
    5959-5964m
    5964-5969m
    5969-5971m
    Core photo at depth: 5972-5977m
    Core photo at depth: 5977-5982m
    Core photo at depth: 5986-5991m
    Core photo at depth: 5982-5985m
    Core photo at depth: 5991-5996m
    5972-5977m
    5977-5982m
    5986-5991m
    5982-5985m
    5991-5996m
    Core photo at depth: 5996-6001m
    Core photo at depth: 6001-6005m
    Core photo at depth: 6038-6043m
    Core photo at depth: 6043-6048m
    Core photo at depth: 6048-6053m
    5996-6001m
    6001-6005m
    6038-6043m
    6043-6048m
    6048-6053m
    Core photo at depth: 6053-6057m
    Core photo at depth: 6057-6060m
    Core photo at depth: 6119-6124m
    Core photo at depth: 6124-6128m
    Core photo at depth: 6160-6165m
    6053-6057m
    6057-6060m
    6119-6124m
    6124-6128m
    6160-6165m
    Core photo at depth: 6165-6170m
    Core photo at depth: 6170-6175m
    Core photo at depth: 6175-6178m
    Core photo at depth: 6223-6228m
    Core photo at depth: 6228-6231m
    6165-6170m
    6170-6175m
    6175-6178m
    6223-6228m
    6228-6231m
  • 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
    TEST1
    0.00
    0.00
    28.10.1995 - 13:00
    YES
  • Lithostratigraphy

  • Composite logs

    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.46
  • Geochemical information

    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    1.19
    pdf
    1.12
  • 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
    33.51
  • Drill stem tests (DST)

    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    5707
    5686
    19.0
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    22.000
    165
    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
    450
    168750
    0.810
    375
  • Logs

    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    4-ARM CAL GR
    2780
    3477
    CBL VDL GR
    5637
    5776
    DCBIL GR
    5260
    6202
    DPIL MAC SLH TTRM
    5845
    6259
    DPIL MAC ZDL CN GR
    5248
    5552
    DPIL MAC ZDL CN SLH TTRM
    5249
    5878
    FMT QDYNE GR
    5273
    5842
    FMT VPC CHT GR
    5926
    6197
    MND DPR
    5260
    5553
    MRIL XDL DN DSL
    5248
    5880
    MWD DPR
    2780
    5260
    MWD DPR
    5553
    5781
    ZDL CN TTRM GR
    5845
    6259
    ZOVSP GR
    2800
    6175
  • 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
    INTERM.
    9 5/8
    5248.0
    12 1/4
    5250.0
    0.00
    LOT
    LINER
    7
    6260.0
    8 1/2
    6260.0
    1.80
    LOT
  • Drilling mud

    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    2810
    1.80
    58.0
    12.0
    OIL BASED
    06.07.1995
    2810
    1.80
    58.0
    12.5
    OIL BASED
    11.07.1995
    2810
    1.76
    56.0
    10.0
    OIL BASED
    11.07.1995
    2810
    1.74
    57.0
    11.0
    OIL BASED
    11.07.1995
    2810
    1.70
    52.0
    10.0
    OIL BASED
    11.07.1995
    2810
    1.70
    53.0
    10.0
    OIL BASED
    12.07.1995
    2810
    1.70
    48.0
    9.0
    OIL BASED
    14.07.1995
    2810
    1.70
    47.0
    9.5
    OIL BASED
    14.07.1995
    2810
    1.70
    46.0
    9.5
    OIL BASED
    17.07.1995
    2810
    1.70
    47.0
    9.0
    OIL BASED
    17.07.1995
    2810
    1.70
    44.0
    9.0
    OIL BASED
    17.07.1995
    2810
    1.70
    40.0
    8.5
    OIL BASED
    18.07.1995
    2810
    1.70
    43.0
    8.0
    OIL BASED
    19.07.1995
    2810
    1.70
    41.0
    8.0
    OIL BASED
    20.07.1995
    2810
    1.80
    59.0
    10.5
    OIL BASED
    03.07.1995
    2810
    1.80
    58.0
    11.5
    OIL BASED
    04.07.1995
    2810
    1.76
    53.0
    10.0
    OIL BASED
    11.07.1995
    2820
    1.66
    47.0
    8.5
    OIL BASED
    28.06.1995
    2820
    1.70
    44.0
    8.0
    OIL BASED
    30.06.1995
    2820
    1.80
    56.0
    9.5
    OIL BASED
    03.07.1995
    2820
    1.80
    60.0
    11.5
    OIL BASED
    03.07.1995
    2859
    1.66
    44.0
    8.0
    OIL BASED
    29.06.1995
    2965
    1.70
    44.0
    8.0
    OIL BASED
    30.06.1995
    3109
    1.80
    56.0
    9.5
    OIL BASED
    03.07.1995
    3221
    1.80
    60.0
    11.5
    OIL BASED
    03.07.1995
    3262
    1.80
    59.0
    10.5
    OIL BASED
    03.07.1995
    3301
    1.80
    58.0
    11.5
    OIL BASED
    04.07.1995
    3362
    1.80
    58.0
    12.0
    OIL BASED
    06.07.1995
    3363
    1.80
    58.0
    12.5
    OIL BASED
    11.07.1995
    3460
    1.76
    56.0
    10.0
    OIL BASED
    11.07.1995
    3465
    1.76
    53.0
    10.0
    OIL BASED
    11.07.1995
    3535
    1.74
    57.0
    11.0
    OIL BASED
    11.07.1995
    3643
    1.70
    52.0
    10.0
    OIL BASED
    11.07.1995
    3730
    1.70
    53.0
    10.0
    OIL BASED
    12.07.1995
    3775
    1.70
    48.0
    9.0
    OIL BASED
    14.07.1995
    3890
    1.70
    47.0
    9.5
    OIL BASED
    14.07.1995
    4099
    1.70
    46.0
    9.5
    OIL BASED
    17.07.1995
    4300
    1.70
    47.0
    9.0
    OIL BASED
    17.07.1995
    4430
    1.70
    44.0
    9.0
    OIL BASED
    17.07.1995
    4457
    1.70
    40.0
    8.5
    OIL BASED
    18.07.1995
    4670
    1.70
    43.0
    8.0
    OIL BASED
    19.07.1995
    4702
    1.70
    41.0
    8.0
    OIL BASED
    20.07.1995
    4900
    1.75
    48.0
    9.5
    OIL BASED
    21.07.1995
    4990
    1.75
    52.0
    10.0
    OIL BASED
    24.07.1995
    4990
    1.75
    50.0
    10.0
    OIL BASED
    24.07.1995
    4990
    1.75
    54.0
    11.0
    OIL BASED
    25.07.1995
    4990
    1.75
    51.0
    10.0
    OIL BASED
    24.07.1995
    4990
    1.75
    54.0
    11.0
    OIL BASED
    26.07.1995
    5041
    1.77
    51.0
    10.0
    OIL BASED
    24.07.1995
    5076
    1.78
    52.0
    10.0
    OIL BASED
    24.07.1995
    5175
    1.78
    50.0
    10.0
    OIL BASED
    24.07.1995
    5245
    1.20
    25.0
    7.0
    OIL BASED
    07.08.1995
    5260
    1.20
    28.0
    7.5
    OIL BASED
    07.08.1995
    5260
    1.20
    28.0
    7.0
    OIL BASED
    07.08.1995
    5260
    1.78
    54.0
    11.0
    OIL BASED
    25.07.1995
    5260
    1.78
    54.0
    11.0
    OIL BASED
    26.07.1995
    5260
    1.20
    28.0
    7.5
    OIL BASED
    08.08.1995
    5260
    1.20
    29.0
    8.0
    OIL BASED
    10.08.1995
    5260
    1.20
    28.0
    7.0
    OIL BASED
    10.08.1995
    5260
    1.20
    28.0
    7.5
    OIL BASED
    15.08.1995
    5260
    1.20
    29.0
    7.0
    OIL BASED
    15.08.1995
    5260
    1.20
    29.0
    7.5
    OIL BASED
    15.08.1995
    5260
    1.20
    29.0
    8.5
    OIL BASED
    17.08.1995
    5260
    1.20
    30.0
    7.5
    OIL BASED
    17.08.1995
    5260
    1.20
    28.0
    8.0
    OIL BASED
    17.08.1995
    5260
    1.21
    27.0
    7.0
    OIL BASED
    07.08.1995
    5260
    1.20
    28.0
    8.0
    OIL BASED
    18.08.1995
    5273
    1.20
    28.0
    8.0
    OIL BASED
    21.08.1995
    5273
    1.20
    28.0
    8.0
    OIL BASED
    21.08.1995
    5273
    1.20
    28.0
    8.0
    OIL BASED
    21.08.1995
    5273
    1.20
    28.0
    8.0
    OIL BASED
    22.08.1995
    5273
    1.20
    31.0
    9.0
    OIL BASED
    23.08.1995
    5273
    1.20
    35.0
    10.0
    OIL BASED
    29.08.1995
    5273
    1.20
    36.0
    10.0
    OIL BASED
    01.09.1995
    5273
    1.20
    35.0
    9.5
    OIL BASED
    30.08.1995
    5280
    1.21
    24.0
    6.0
    OIL BASED
    07.08.1995
    5310
    1.20
    25.0
    6.5
    OIL BASED
    07.08.1995
    5345
    1.20
    26.0
    7.5
    OIL BASED
    07.08.1995
    5371
    1.20
    25.0
    7.0
    OIL BASED
    07.08.1995
    5379
    1.20
    26.0
    7.5
    OIL BASED
    07.08.1995
    5380
    1.20
    28.0
    8.0
    OIL BASED
    21.08.1995
    5432
    1.20
    27.0
    7.0
    OIL BASED
    07.08.1995
    5457
    1.20
    28.0
    7.5
    OIL BASED
    07.08.1995
    5499
    1.20
    28.0
    7.0
    OIL BASED
    07.08.1995
    5536
    1.20
    28.0
    7.5
    OIL BASED
    08.08.1995
    5553
    1.20
    29.0
    8.0
    OIL BASED
    10.08.1995
    5613
    1.20
    28.0
    7.0
    OIL BASED
    10.08.1995
    5645
    1.20
    28.0
    7.5
    OIL BASED
    15.08.1995
    5711
    1.20
    29.0
    7.0
    OIL BASED
    15.08.1995
    5737
    1.20
    28.0
    8.0
    OIL BASED
    22.08.1995
    5737
    1.20
    28.0
    8.0
    OIL BASED
    21.08.1995
    5737
    1.20
    31.0
    9.0
    OIL BASED
    23.08.1995
    5737
    1.20
    28.0
    8.0
    OIL BASED
    21.08.1995
    5753
    1.20
    29.0
    7.5
    OIL BASED
    15.08.1995
    5781
    1.20
    29.0
    8.5
    OIL BASED
    17.08.1995
    5846
    1.20
    30.0
    7.5
    OIL BASED
    17.08.1995
    5890
    1.20
    28.0
    8.0
    OIL BASED
    17.08.1995
    5890
    1.20
    32.0
    9.0
    OIL BASED
    25.08.1995
    5890
    1.20
    30.0
    7.5
    OIL BASED
    29.08.1995
    5890
    1.20
    33.0
    9.0
    OIL BASED
    25.08.1995
    5890
    1.20
    28.0
    8.0
    OIL BASED
    18.08.1995
    5893
    1.20
    29.0
    8.5
    OIL BASED
    29.08.1995
    5912
    1.20
    33.0
    8.5
    OIL BASED
    29.08.1995
    5948
    1.20
    35.0
    10.0
    OIL BASED
    29.08.1995
    5959
    1.20
    35.0
    9.5
    OIL BASED
    30.08.1995
    5972
    1.20
    36.0
    10.0
    OIL BASED
    01.09.1995
  • 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