Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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6506/12-7

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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.
    6506/12-7
    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.
    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.
    6506/12-7
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    ST 8403 - 463 SP. 322
    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.
    544-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.
    101
    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,
    04.05.1987
    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.
    12.08.1987
    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.
    12.08.1989
    Publication date
    Date quality control of the wellbore information was completed, so it can be published on the internet as a 'Well Data Summary Sheet' wellbore with more information available than other wellbores.
    28.06.2007
    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.
    GAS/CONDENSATE
    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.
    ILE 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.
    TILJE FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    29.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    267.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4840.0
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    167
    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.
    TILJE FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    65° 10' 4.38'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    6° 54' 38.87'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7228966.15
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    402107.96
    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.
    300

  • Wellbore history
    General
    Well 6506/12-7 was drilled as an exploration well on the Northeast Smørbukk structure. The primary purpose was to find hydrocarbon accumulations of significant amounts in the Middle and Early Jurassic sandstone reservoirs. Secondary objectives were to check for hydrocarbon accumulations deeper than the structural closure of the main field. The well should also verify the geophysical and structural interpretation and improve the geological, paleontological and geochemical understanding of the area. Total depth was to be in rocks of Triassic age or 4000 m in order to satisfy the licence commitment.
    Operations and results
    Well 6506/12-7 was spudded with the semi-submersible installation Dyvi Delta on 7 April 1987 and drilled to TD at 4840 m in the Early Jurassic Tilje Formation. Drilling proceeded without significant problems. The well was drilled with spud mud down to 597 m, with gypsum/polymer mud from 597 m to 4427 m, and with a pre-hydrated Bentonite/Lignosulphonate mud system from 4427 m to TD. No shallow gas was encountered.
    The first show appeared in the Lange Formation at 3791 - 3794 m. During coring there were oil shows in Garn and Ile Formations, while Ti1je only contained small traces of oil. Both cores and logs indicated that Garn and Ile Formations were hydrocarbon bearing down to ca 4538 m, while Ti1je Formation was indicated to be water bearing. The porosity was assumed to be between 8 and 12 %. Mobil wanted to test the Ti1je Formation to get a fluid sample to understand the logs better. This was a wise decision because the formation produced oil at very good rates. The Garn Formation on the other hand did not produce any formation fluid when tested. The oil/water contact in the Tilje Formation was not found because the logs did not give clear data.
    Eight cores were cut in the well with a total recovery of 62.6 m core. One core was cut in the interval 4053 - 4058 m (Spekk Formation), two cores from 4427.5 to 4439.2 m bas Garn Formation), four cores in the interval 4467 - 4502 m (Not-Ile Formations), and one core from 4672 to 4700 m (all of Ror Formation with base Tofte and top Tilje). RFT fluid samples were taken at 4420 m (Garn), 4496.5 m (Ile), and 4708 m (Tilje).
    The well was permanently abandoned on 12 August 1987 as a gas/condensate appraisal.
    Testing
    Four DSTs were performed in this well.
    DST 1 in the interval 4741 - 4748 m in the Tilje Formation produced 520 Sm3 condensate, 230000 Sm3 gas and no water through a 32/64" choke. The GOR was 442 Sm3/Sm3, the condensate density was 0.820 g/cm3, and the gas gravity was 0.770 (air = 1). Maximum down-hole temperature recorded in the test was 164 deg C.
    DST 2 in the interval 4702 - 4707 m in the Tilje Formation produced 200 Sm3 condensate, 145000 Sm3 gas and no water through a 20/64" choke. The GOR was 725 Sm3/Sm3, the condensate density was 0.818 g/cm3, and the gas gravity was 0.785 (air = 1). Maximum down-hole temperature recorded in the test was 164 deg C.
    DST 3 in the interval 4474 - 4514 m in the Ile Formation produced 70 Sm3 condensate, 110000 Sm3 gas and 4 - 20% water through a 20/64" choke. The GOR was 1570 Sm3/Sm3, the condensate density was 0.790 g/cm3, and the gas gravity was 0.745 (air = 1). Maximum down-hole temperature recorded in the test was 136 deg C.
    DST 4 in the interval 4414 - 4439 m in the lower Garn Formation flowed 1.7 m3 fluids into the well bore. Only gas and mud came to surface during reverse circulation. No formation fluid was observed.

  • 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]
    610.00
    4840.00

  • 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
    4053.0
    4053.5
    [m ]
    2
    4427.5
    4435.5
    [m ]
    3
    4436.0
    4439.1
    [m ]
    4
    4467.0
    4468.1
    [m ]
    5
    4468.5
    4475.8
    [m ]
    6
    4477.5
    4483.0
    [m ]
    7
    4483.5
    4502.5
    [m ]
    8
    4672.0
    4700.0
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    72.6
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 4053-4430m
    Core photo at depth: 4430-4435m
    Core photo at depth: 4435-4439m
    Core photo at depth: 4461-4471m
    Core photo at depth: 4471-4475m
    4053-4430m
    4430-4435m
    4435-4439m
    4461-4471m
    4471-4475m
    Core photo at depth: 4477-4482m
    Core photo at depth: 4482-4487m
    Core photo at depth: 4487-4492m
    Core photo at depth: 4492-4497m
    Core photo at depth: 4497-4502m
    4477-4482m
    4482-4487m
    4487-4492m
    4492-4497m
    4497-4502m
    Core photo at depth: 4502-4676m
    Core photo at depth: 4676-4681m
    Core photo at depth: 4681-4686m
    Core photo at depth: 4686-4691m
    Core photo at depth: 4691-4696m
    4502-4676m
    4676-4681m
    4681-4686m
    4686-4691m
    4691-4696m
    Core photo at depth: 4696-4700m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    4696-4700m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    4388.0
    [m]
    DC
    RRI
    4394.0
    [m]
    DC
    RRI
    4397.0
    [m]
    DC
    RRI
    4412.0
    [m]
    DC
    RRI
    4418.0
    [m]
    DC
    RRI
    4424.0
    [m]
    DC
    RRI
    4439.0
    [m]
    C
    RRI
    4445.0
    [m]
    DC
    RRI
    4451.0
    [m]
    DC
    RRI
    4457.0
    [m]
    DC
    RRI
    4463.0
    [m]
    DC
    RRI
    4467.0
    [m]
    C
    RRI
    4505.0
    [m]
    DC
    RRI
    4511.0
    [m]
    DC
    RRI
    4517.0
    [m]
    DC
    RRI
    4523.0
    [m]
    DC
    RRI
    4529.0
    [m]
    DC
    RRI
    4535.0
    [m]
    DC
    RRI
    4541.0
    [m]
    DC
    RRI
    4547.0
    [m]
    DC
    RRI
    4559.0
    [m]
    DC
    RRI
    4565.0
    [m]
    DC
    RRI
    4571.0
    [m]
    DC
    RRI
    4577.0
    [m]
    DC
    RRI
    4583.0
    [m]
    DC
    RRI
    4589.0
    [m]
    DC
    RRI
    4595.0
    [m]
    DC
    RRI
    4601.0
    [m]
    DC
    RRI
    4607.0
    [m]
    DC
    RRI
    4613.0
    [m]
    DC
    RRI
    4619.0
    [m]
    DC
    RRI
    4625.0
    [m]
    DC
    RRI
    4631.0
    [m]
    DC
    RRI
    4637.0
    [m]
    DC
    RRI
    4643.0
    [m]
    DC
    RRI
    4655.0
    [m]
    DC
    RRI
    4661.0
    [m]
    DC
    RRI
    4781.0
    [m]
    DC
    RRI
    4787.0
    [m]
    DC
    RRI
    4793.0
    [m]
    DC
    RRI
    4799.0
    [m]
    DC
    RRI
    4805.0
    [m]
    DC
    RRI
    4811.0
    [m]
    DC
    RRI
    4818.0
    [m]
    DC
    RRI
    4823.0
    [m]
    DC
    RRI
    4829.0
    [m]
    DC
    RRI

  • 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
    4741.00
    4748.00
    18.07.1982 - 02:00
    YES
    DST
    TEST2
    4702.00
    4707.00
    24.07.1982 - 14:25
    YES
    DST
    TEST3
    4474.00
    4512.00
    30.07.1982 - 00:00
    YES

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.77

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.12
    pdf
    2.46
    pdf
    0.16
    pdf
    0.41

  • 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
    30.60

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    4741
    4748
    12.7
    2.0
    4702
    4707
    7.9
    3.0
    4474
    4514
    15.9
    4.0
    4414
    4439
    0.0
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    2.0
    3.0
    4.0
    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
    520
    145000
    0.820
    0.770
    442
    2.0
    200
    145000
    0.818
    0.785
    725
    3.0
    70
    110000
    0.790
    0.745
    1571
    4.0

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CDL CNL SPL GR
    4387
    4840
    DIFL ACL CDL
    589
    4379
    DIFL ACL GR
    4200
    4841
    DLL MLL GR
    4387
    4841
    HPFM
    4420
    4813
    HPFM GR
    4420
    4705
    HRDIP
    4385
    4840
    MWD - GR RES DIR
    410
    3321
    VELOCITY
    270
    4800

  • 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
    406.5
    36
    410.0
    0.00
    LOT
    SURF.COND.
    20
    589.0
    26
    596.0
    1.51
    LOT
    INTERM.
    13 3/8
    2203.0
    17 1/2
    2221.0
    1.81
    LOT
    INTERM.
    9 5/8
    4389.0
    12 1/4
    4427.0
    1.80
    LOT
    LINER
    7
    4838.0
    8 1/2
    4840.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    463
    1.45
    1700.0
    6.3
    WATER BASED
    11.08.1987
    2050
    1.65
    1500.0
    2.5
    WATER BASED
    10.08.1987
    2221
    1.45
    1700.0
    7.2
    WATER BASED
    21.05.1987
    2450
    1.62
    2100.0
    6.7
    WATER BASED
    03.06.1987
    2450
    1.62
    2200.0
    7.2
    WATER BASED
    01.06.1987
    2450
    1.62
    2100.0
    5.9
    WATER BASED
    01.06.1987
    2450
    1.62
    2300.0
    7.2
    WATER BASED
    02.06.1987
    2450
    1.62
    2300.0
    8.5
    WATER BASED
    04.06.1987
    2450
    1.62
    2300.0
    5.9
    WATER BASED
    05.06.1987
    2815
    1.62
    670.0
    8.0
    WATER BASED
    25.05.1987
    2934
    1.62
    560.0
    7.6
    WATER BASED
    25.05.1987
    2974
    1.62
    520.0
    7.2
    WATER BASED
    25.05.1987
    3150
    1.62
    630.0
    8.0
    WATER BASED
    27.05.1987
    3231
    1.62
    560.0
    8.9
    WATER BASED
    29.05.1987
    3300
    1.62
    550.0
    8.0
    WATER BASED
    29.05.1987
    3379
    1.62
    2000.0
    8.9
    WATER BASED
    01.06.1987
    3760
    1.62
    2300.0
    7.2
    WATER BASED
    09.06.1987
    3841
    1.62
    1900.0
    8.0
    WATER BASED
    09.06.1987
    3934
    1.62
    2200.0
    6.8
    WATER BASED
    09.06.1987
    4016
    1.62
    2300.0
    6.8
    WATER BASED
    09.06.1987
    4053
    1.62
    2400.0
    6.4
    WATER BASED
    10.06.1987
    4058
    1.67
    2200.0
    7.6
    WATER BASED
    11.06.1987
    4092
    1.65
    1800.0
    5.9
    WATER BASED
    12.06.1987
    4167
    1.65
    1900.0
    5.9
    WATER BASED
    15.06.1987
    4182
    1.65
    1500.0
    2.5
    WATER BASED
    10.08.1987
    4260
    1.65
    1900.0
    5.5
    WATER BASED
    15.06.1987
    4354
    1.65
    2500.0
    5.9
    WATER BASED
    15.06.1987
    4369
    1.20
    1400.0
    4.2
    WATER BASED
    25.06.1987
    4408
    1.25
    900.0
    1.7
    WATER BASED
    10.08.1987
    4425
    1.65
    2400.0
    5.1
    WATER BASED
    16.06.1987
    4427
    1.65
    2200.0
    4.2
    WATER BASED
    17.06.1987
    4427
    1.65
    2200.0
    3.8
    WATER BASED
    18.06.1987
    4427
    1.65
    2000.0
    4.2
    WATER BASED
    19.06.1987
    4427
    1.65
    2000.0
    4.2
    WATER BASED
    22.06.1987
    4428
    1.25
    1600.0
    4.2
    WATER BASED
    22.06.1987
    4436
    1.25
    1000.0
    3.4
    WATER BASED
    23.06.1987
    4452
    1.25
    1000.0
    3.4
    WATER BASED
    24.06.1987
    4455
    1.25
    1000.0
    1.7
    WATER BASED
    05.08.1987
    4455
    1.25
    800.0
    1.7
    WATER BASED
    07.08.1987
    4478
    1.25
    1600.0
    4.2
    WATER BASED
    26.06.1987
    4502
    1.25
    1300.0
    4.2
    WATER BASED
    29.06.1987
    4560
    1.25
    1500.0
    4.7
    WATER BASED
    29.06.1987
    4620
    1.25
    1600.0
    5.1
    WATER BASED
    29.06.1987
    4656
    1.25
    1700.0
    5.1
    WATER BASED
    30.06.1987
    4672
    1.25
    800.0
    1.3
    WATER BASED
    28.07.1987
    4672
    1.25
    800.0
    1.7
    WATER BASED
    29.07.1987
    4672
    1.25
    800.0
    1.3
    WATER BASED
    31.07.1987
    4672
    1.25
    900.0
    2.1
    WATER BASED
    03.08.1987
    4672
    1.25
    900.0
    1.7
    WATER BASED
    04.08.1987
    4688
    1.25
    1500.0
    4.7
    WATER BASED
    01.07.1987
    4692
    1.25
    800.0
    1.3
    WATER BASED
    27.07.1987
    4720
    1.25
    800.0
    1.7
    WATER BASED
    23.07.1987
    4720
    1.25
    900.0
    1.3
    WATER BASED
    24.07.1987
    4720
    1.25
    400.0
    1.7
    WATER BASED
    27.07.1987
    4720
    1.25
    800.0
    1.3
    WATER BASED
    27.07.1987
    4720
    1.25
    900.0
    1.7
    WATER BASED
    22.07.1987
    4730
    1.25
    900.0
    1.7
    WATER BASED
    21.07.1987
    4752
    1.25
    1600.0
    4.2
    WATER BASED
    02.07.1987
    4838
    1.25
    1900.0
    5.1
    WATER BASED
    13.07.1987
    4838
    1.25
    1300.0
    2.5
    WATER BASED
    13.07.1987
    4838
    1.26
    1200.0
    2.5
    WATER BASED
    13.07.1987
    4838
    1.26
    1100.0
    2.5
    WATER BASED
    13.07.1987
    4838
    1.26
    1100.0
    2.5
    WATER BASED
    14.07.1987
    4838
    1.25
    1000.0
    5.2
    WATER BASED
    15.07.1987
    4838
    1.26
    1000.0
    2.5
    WATER BASED
    17.07.1987
    4838
    1.25
    900.0
    1.7
    WATER BASED
    20.07.1987
    4838
    1.25
    2300.0
    7.6
    WATER BASED
    13.07.1987
    4838
    1.25
    1600.0
    3.8
    WATER BASED
    16.07.1987
    4838
    1.25
    1000.0
    2.1
    WATER BASED
    20.07.1987
    4840
    1.25
    1900.0
    5.1
    WATER BASED
    03.07.1987
    4840
    1.25
    2300.0
    4.6
    WATER BASED
    06.07.1987
    4840
    1.25
    2200.0
    4.2
    WATER BASED
    06.07.1987
    4840
    1.25
    2400.0
    7.2
    WATER BASED
    06.07.1987
    4840
    1.25
    2100.0
    6.3
    WATER BASED
    07.07.1987

  • 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