Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
25.11.2024 - 01:30
Time of last synchronization with Norwegian Offshore Directorate's internal systems

6506/12-3

Export: PDF icon PDF

  • General information
    General information
    Attribute Value
    Wellbore name
    Official name of wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    6506/12-3
    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
    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.
    6506/12-3
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    ST 8403 - 402 A SP. 1112
    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.
    456-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.
    138
    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,
    02.03.1985
    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.
    17.07.1985
    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.
    17.07.1987
    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.
    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.
    YES
    1st level with HC, age
    Age of lithostratigraphic unit, 1st level, where hydrocarbons were encountered. Examples of legal values: CRETACEOUS, EARLY CRETACEOUS, LATE JURASSIC, EOCENE. See also Norwegian Offshore Directorate bulletins.
    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
    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.
    MIDDLE 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.
    FANGST GP
    3rd level with HC, age
    Age of lithostratigraphic unit, 3rd level, where hydrocarbons were encountered. Examples of legal values: CRETACEOUS, EARLY CRETACEOUS, LATE JURASSIC, EOCENE.
    EARLY JURASSIC
    3rd level with HC, formation
    Name of lithostartigraphic unit, 3rd 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.
    22.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    301.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4360.0
    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).
    4359.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    4.4
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    152
    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° 1' 31.09'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    6° 53' 27.35'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7213112.80
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    400646.78
    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.
    468

  • Wellbore history
    General
    Wildcat well 6506/12-3 is a replacement well for 6506/12-2, which was abandoned at 955 m due to technical problems. The new well was designed to test the hydrocarbon potential of the Beta structure in the southeast part of the
    block. The main object was Middle Jurassic sandstones, secondary targets were possible Cretaceous sands, Early Jurassic sandstones and sandstones within the Coal Beds.
    Operations and results
    Well 6506/12-3 was spudded with the semi-submersible installation Ross Isle, 47 m from the junked well 6506/12-2. It was spudded on 2 March 1985 and drilled to TD at 4360 m in the Early Jurassic Tilje Formation (formerly called the Aldra Formation). No significant technical problems occurred during the operations. From 0600 hours on 15 June, during the testing phase, the rig was on strike for 13 days. The well was drilled with seawater/gel down to 955 m, with gypsum/lignosulphonate mud from 955 m to 3831 m, and with gel/lignosulphonate mud from 3831 m to TD. The shallow gas present at 572 m in 6506/12-2 was not encountered in 6506/12-3.
    Top Middle Jurassic Garn Formation (formerly Tomma Formation) came in at 3822 m, 80 m above the prognosis. The Early Jurassic Tilje Formation sandstone (Aldra Formation) came in at 4147 m. Hydrocarbons were encountered both in the Middle and the Early Jurassic sandstones, with a hydrocarbon/water contact at 4216 m in the Tilje Formation. Late Cretaceous Lysing sandstones at the top of the Cromer Knoll Group (Finnvær Group) was also hydrocarbon bearing. A total of 242 m of hydrocarbon bearing sands was proven. Shows were only recorded in association with the hydrocarbon bearing sections.
    A total of 289 m core was recovered in 15 cores from the Garn, Not, Ile, Ror, and Tilje Formations between 3836 and 4269 m. Six RFT runs were completed in the Early - Middle Jurassic section in well 6506/12-3. A total of 47 pressure tests gave reliable results. In addition, segregated fluid samples were collected at 3863 m, 4231 m, 4308.1 m, and 4310.9 m.
    The well was permanently abandoned on 17 July as an oil/condensate/gas discovery.
    Testing
    Six DST tests were performed:
    DST 1 at 4222 - 4241 m in the Tilje Formation flowed 742 Sm3 light oil and 373300 Sm3 gas /day through a 22.2 mm choke. The GOR was 503 Sm3/Sm3, the oil density was 0.802 g/cm3 and the gas gravity was 0.847 (air = 1). The DST temperature was 150 deg C.
    DST 2 at 4165 - 4170 m in the Tilje Formation flowed 53.8 Sm3 light oil and 66800 Sm3 gas /day through a 25.4 mm choke. The GOR was 1241 Sm3/Sm3, the oil density was 0.820 g/cm3 and the gas gravity was 0.907 (air = 1). The DST temperature was 143.8 deg C.
    DST 3 at 3960 - 3980 m in the Ile Formation flowed 328.9 Sm3 condensate and 453100 Sm3 gas /day through a 31.8 mm choke. The GOR was 1378 Sm3/Sm3, the oil density was 0.787 g/cm3 and the gas gravity was 0.745 (air = 1). The DST temperature was 143.4 deg C.
    DST 4 at 3880 - 3890 m in the Garn Formation flowed 777.3 Sm3 light oil and 396500 Sm3 gas /day through a 23.8 mm choke. The GOR was 510 Sm3/Sm3, the oil density was 0.820 g/cm3 and the gas gravity was 0.764 (air = 1). The DST temperature was 141.8 deg C.
    DST 5 at 3822 - 3836 m in the topmost Garn Formation flowed 156.2 Sm3 oil and 37600 Sm3 gas /day through a 12.7 mm choke. The GOR was 241 Sm3/Sm3, the oil density was 0.830 g/cm3 and the gas gravity was 0.787 (air = 1). The DST temperature was 141 deg C.
    DST 6 at 3162 - 3173 m in the Lysing Formation flowed 582.7 Sm3 light oil, 712.2 m3 water, and 109600 Sm3 gas /day through a 19.1 mm choke. The GOR was 188 Sm3/Sm3, the oil density was 0.807 g/cm3 and the gas gravity was 0.780 (air = 1). This was the only test with water production.

  • 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]
    950.00
    4360.00

  • 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
    3836.0
    3845.5
    [m ]
    2
    3845.5
    3855.0
    [m ]
    3
    3855.0
    3864.2
    [m ]
    4
    3864.2
    3882.6
    [m ]
    5
    3884.0
    3911.2
    [m ]
    6
    3911.2
    3926.0
    [m ]
    7
    3949.0
    3977.0
    [m ]
    8
    3977.0
    4003.0
    [m ]
    9
    4004.0
    4017.9
    [m ]
    10
    4116.0
    4144.0
    [m ]
    11
    4144.0
    4170.0
    [m ]
    12
    4170.0
    4197.5
    [m ]
    13
    4197.5
    4221.5
    [m ]
    14
    4221.5
    4249.5
    [m ]
    15
    4249.5
    4268.0
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    308.5
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 3836-3842m
    Core photo at depth: 3842-3845m
    Core photo at depth: 3845-3851m
    Core photo at depth: 3851-3855m
    Core photo at depth: 3855-3861m
    3836-3842m
    3842-3845m
    3845-3851m
    3851-3855m
    3855-3861m
    Core photo at depth: 3861-3864m
    Core photo at depth: 3864-3869m
    Core photo at depth: 3870-3876m
    Core photo at depth: 3878-3882m
    Core photo at depth: 3882-3883m
    3861-3864m
    3864-3869m
    3870-3876m
    3878-3882m
    3882-3883m
    Core photo at depth: 3884-3890m
    Core photo at depth: 3890-3896m
    Core photo at depth: 3896-3902m
    Core photo at depth: 3902-3908m
    Core photo at depth: 3908-3917m
    3884-3890m
    3890-3896m
    3896-3902m
    3902-3908m
    3908-3917m
    Core photo at depth: 3911-3917m
    Core photo at depth: 3917-3923m
    Core photo at depth: 3923-3925m
    Core photo at depth: 3949-3955m
    Core photo at depth: 3955-3961m
    3911-3917m
    3917-3923m
    3923-3925m
    3949-3955m
    3955-3961m
    Core photo at depth: 3961-3967m
    Core photo at depth: 3967-3973m
    Core photo at depth: 3973-3977m
    Core photo at depth: 3977-3983m
    Core photo at depth: 3983-3989m
    3961-3967m
    3967-3973m
    3973-3977m
    3977-3983m
    3983-3989m
    Core photo at depth: 3989-3995m
    Core photo at depth: 3995-4001m
    Core photo at depth: 4001-4003m
    Core photo at depth: 4004-4010m
    Core photo at depth: 4010-4016m
    3989-3995m
    3995-4001m
    4001-4003m
    4004-4010m
    4010-4016m
    Core photo at depth: 4016-4017m
    Core photo at depth: 4116-4122m
    Core photo at depth: 4122-4128m
    Core photo at depth: 4128-4134m
    Core photo at depth: 4134-4140m
    4016-4017m
    4116-4122m
    4122-4128m
    4128-4134m
    4134-4140m
    Core photo at depth: 4140-4144m
    Core photo at depth: 4144-4150m
    Core photo at depth: 4150-4156m
    Core photo at depth: 4156-4162m
    Core photo at depth: 4162-4168m
    4140-4144m
    4144-4150m
    4150-4156m
    4156-4162m
    4162-4168m
    Core photo at depth: 4168-4170m
    Core photo at depth: 4170-4176m
    Core photo at depth: 4176-4182m
    Core photo at depth: 4182-4188m
    Core photo at depth: 4188-4194m
    4168-4170m
    4170-4176m
    4176-4182m
    4182-4188m
    4188-4194m
    Core photo at depth: 4194-4197m
    Core photo at depth: 4197-4203m
    Core photo at depth: 4203-4209m
    Core photo at depth: 4209-4215m
    Core photo at depth: 4215-4221m
    4194-4197m
    4197-4203m
    4203-4209m
    4209-4215m
    4215-4221m
    Core photo at depth: 4221-4222m
    Core photo at depth: 4222-4227m
    Core photo at depth: 4227-4233m
    Core photo at depth: 4233-4239m
    Core photo at depth: 4239-4245m
    4221-4222m
    4222-4227m
    4227-4233m
    4233-4239m
    4239-4245m
    Core photo at depth: 4245-4249m
    Core photo at depth: 4249-4255m
    Core photo at depth: 4255-4261m
    Core photo at depth: 4261-4267m
    Core photo at depth: 4267-4268m
    4245-4249m
    4249-4255m
    4255-4261m
    4261-4267m
    4267-4268m

  • 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
    4222.00
    4241.00
    21.05.1985 - 23:20
    YES
    DST
    DST2
    4143.00
    4148.00
    28.05.1985 - 00:30
    YES
    DST
    DST3
    3960.00
    3980.00
    04.06.1985 - 01:30
    YES
    DST
    DST4
    3880.00
    3890.00
    10.06.1985 - 00:00
    YES
    DST
    DST5
    3822.00
    3836.00
    03.07.1985 - 10:10
    YES
    DST
    DST6
    3162.00
    3173.00
    08.07.1985 - 16:40
    YES

  • Lithostratigraphy

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.88
    pdf
    0.54
    pdf
    4.69
    pdf
    1.16
    pdf
    5.00
    pdf
    0.15

  • 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
    23.72
    pdf
    2.73

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    4222
    4241
    25.4
    2.0
    4165
    4170
    25.4
    3.0
    3960
    3980
    25.4
    4.0
    3881
    3890
    28.6
    5.0
    3822
    3836
    9.5
    6.0
    3162
    3173
    32.0
    6.1
    3162
    3173
    15.8
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    83.000
    120
    2.0
    10.000
    120
    3.0
    7.000
    118
    4.0
    9.000
    121
    5.0
    7.000
    23.000
    120
    6.0
    14.000
    40.000
    6.1
    128.000
    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
    820
    372000
    0.810
    0.803
    454
    2.0
    54
    68000
    0.820
    0.907
    1264
    3.0
    297
    445000
    0.795
    0.755
    1500
    4.0
    790
    416000
    0.820
    0.765
    526
    5.0
    100
    29000
    0.830
    0.797
    290
    6.0
    92
    28000
    0.785
    0.797
    304
    6.1
    329
    57000
    0.814
    0.797
    173

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL VDL CCL GR
    347
    2236
    CBL VDL CCL GR
    2390
    3797
    CBL VDL CCL GR
    3659
    4287
    CEQL
    3659
    4298
    CST
    2281
    3824
    CST
    4078
    4351
    DIL LSS GR
    3810
    4359
    DLL MSFL GR SP
    3809
    4357
    ISF LSS MS SP GR
    940
    3830
    LDL CNL NGT GR
    2236
    4362
    LDL GR
    940
    2249
    MWD - GR RES DIR
    940
    4358
    NGS
    2236
    4362
    RFT GR
    3840
    3961
    RFT GR
    3863
    3863
    RFT GR
    3865
    4335
    RFT GR
    3961
    4208
    RFT GR
    4302
    4306
    RFT GR
    4309
    4343
    SHDT GR
    2236
    4362
    VELOCITY
    600
    4350

  • 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
    404.0
    36
    404.0
    0.00
    LOT
    SURF.COND.
    20
    940.0
    26
    955.0
    1.65
    LOT
    INTERM.
    13 3/8
    2240.0
    17 1/2
    2280.0
    1.87
    LOT
    INTERM.
    9 5/8
    3809.0
    12 1/4
    3831.0
    1.83
    LOT
    LINER
    7
    4359.0
    8 1/2
    4360.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    2043
    1.25
    11.0
    7.5
    WATERBASED
    19.03.1985
    2043
    1.25
    11.0
    7.5
    WATER BASED
    19.03.1985
    2131
    1.40
    12.0
    7.0
    WATER BASED
    19.03.1985
    2131
    1.40
    12.0
    7.0
    WATERBASED
    19.03.1985
    2206
    1.48
    17.0
    10.0
    WATERBASED
    19.03.1985
    2206
    1.48
    17.0
    10.0
    WATER BASED
    19.03.1985
    2250
    1.57
    17.0
    10.0
    WATERBASED
    19.03.1985
    2250
    1.57
    17.0
    10.0
    WATER BASED
    19.03.1985
    3290
    1.65
    240.0
    7.0
    WATERBASED
    02.04.1985
    3290
    1.65
    240.0
    7.0
    WATER BASED
    02.04.1985
    3711
    1.70
    21.0
    6.2
    WATER BASED
    10.04.1985
    3711
    1.70
    21.0
    6.2
    WATERBASED
    10.04.1985
    3822
    1.20
    WATER BASED
    17.04.1985
    3830
    1.73
    24.0
    WATERBASED
    15.04.1985
    3830
    1.73
    24.0
    WATER BASED
    15.04.1985
    4360
    1.12
    10.0
    9.0
    WATER BASED
    07.05.1985

  • 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
    0.24