Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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24.11.2024 - 01:27
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34/10-33

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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.
    34/10-33
    Type
    Wellbore type. Legal values: EXPLORATION, DEVELOPMENT, OTHER (see 'Purpose' for more information)
    EXPLORATION
    Purpose
    Final classification of the wellbore.

    Legal values for exploration wellbores:
    WILDCAT, APPRAISAL, WILDCAT-CCS, APPRAISAL-CCS.

    Legal values for development wellbores:
    OBSERVATION, PRODUCTION, INJECTION, INJECTION-CCS, OBSERVATION-CCS.

    Legal values for other wellbores:
    SOIL DRILLING (drilling in connection with track surveys and other subsurface surveys to investigate the soil conditions prior to placement of facilities),
    SHALLOW GAS (drilling to investigate shallow gas before the first 'real' drilling on the location),
    PILOT (drilling to investigate the geology and fluid connectors for location of the main wellbore),
    SCIENTIFIC (drilling according to Law of Scientific research and exploration),
    STRATIGRAPHIC (driling according to Law of Petroleum activities §2-1).
    APPRAISAL
    Status
    Status for the wellbore. Legal values are:

    BLOWOUT: A blowout has occurred in the well.
    CLOSED: A development wellbore that has been closed in a shorter or longer periode. Also applies to development wellbores where drilling is completed, but production/injection has not yet been reported.
    DRILLING: The well is in the drilling phase - can be active drilling, logging, testing or plugging,
    JUNKED: The drilling operation has been terminated due to technical problems.
    P&A: Exploration: The well is plugged and abandoned, and can not be reentered for further use. Development wells: The production/injection from/to the well is stopped and the well is plugged. The wellhead is removed or else made unavailable for further well operations.
    PLUGGED: The wellbore has been plugged, but the upper parts of the wellbore can be re-used. A sidetrack might be drilled at a later stage.
    PRODUCING: It was produced from the wellbore at the time of the operators last monthly report to the Norwegian Offshore Directorate.
    INJECTING: It was injected to the wellbore at the time of the operators last monthly report to the Norwegian Offshore Directorate.
    PREDRILLED: The upper part of the well has been drilled, usually as part of a batch-drilling campaign covering several wellbores.
    RE-CLASS TO DEV: Exploration wellbore that is reclassified to a development wellbore.
    RE-CLASS TO TEST: Exploration wellbore that is reclassified to test production.
    SUSPENDED: The drilling operation in the wellbore has been temporarily stopped. The current plan is to continue drilling later on.
    P&A
    Factmaps in new window
    Main area
    Name of the area on the Norwegian Continental Shelf where the wellbore is located. Legal values: BARENTS SEA, NORWEGIAN SEA, NORTH SEA.
    NORTH SEA
    Field
    Name of the field the wellbore is related to.
    Discovery
    Name of the discovery the wellbore is related to.
    Well name
    Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    34/10-33
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    ST 8134 - 156 CELLEPKT. 296
    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.
    591-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.
    82
    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,
    25.09.1988
    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.
    15.12.1988
    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.
    15.12.1990
    Publication date
    Date quality control of the wellbore information was completed, so it can be published on the internet as a 'Well Data Summary Sheet' wellbore with more information available than other wellbores.
    01.01.2012
    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.
    BRENT GP
    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.
    134.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3870.0
    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).
    3850.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    20
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    135
    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.
    STATFJORD GP
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    61° 7' 34.44'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 12' 57.1'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6777262.00
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    457756.18
    UTM zone
    Universal Transverse Mercator zone. Examples of legal values: 31, 32, 33, 34.
    31
    NPDID wellbore
    Norwegian Offshore Directorate's unique id for the wellbore.
    1302

  • Wellbore history
    General
    Well 34/10-33 was the sixth well drilled to reservoir level on the Gullfaks South structure. The main objective of the well was to appraise the oil and gas reserves in the Brent Group on the northern part of the structure. The gas/oil and oil/water contacts were to be confirmed at 3324 m and 3395 m MSL respectively. Secondary objective was to penetrate 50 m of the Statfjord Formation to obtain data to better understand the structural development in the area, and also update the geological model for the upper part of the formation. A positive result would lead to the drilling of a horizontal testing well as a sidetrack from this well.
    Operations and results
    Well was spudded with the semi-submersible installation West Delta on 25 September 1988 and drilled to TD at 3870 m in the Early Jurassic Statfjord Formation. There was some shallow gas at 477 - 478 m. Due to this the 20" casing was set at 450 m. There was a problem with a leakage in the BOP. The drill string got stuck when setting the 13 3/8" casing and the MWD and drill bit had to be changed. The well was close to vertical down to ca 2500 m. From there the well built inclination gradually up to 20 deg at TD. At TD true vertical depth is estimated to be ca 20 m less than measured depth. The well was drilled with spud mud down to 483 m, with gypsum/polymer mud from 483 m to 3161 m, and with gel/lignosulphonate/lignite mud from 3161 m to TD.
    Top Brent Group, Tarbert Formation came in at 3186 m with gas and oil. FMT data showed a gas/oil contact at 3268 m, 85 m higher than prognosed. Approximately 150 m of oil was found vertically down to top Dunlin Group at 3424 m, much more than expected. No oil/water contact was seen. There was a pressure shift of 1.5 - 2 bar at around 3350 m, indicating two separate compartments in the oil zone. This had not been observed in the previous wells on Gullfaks South. Due to the large amount of oil in the Brent Group, the oil in place estimate was adjusted to 50 - 60 million Sm3.
    Eighteen cores were cut in the well. One core was cut from 3152 to 3161.5 m, 14 cores in the interval 3188 to 3435 m and 3 cores from 3799 to 3840 m. The core depth was found to be from 1.00 to 3.75 m less than loggers' depth. Segregated fluid samples were obtained at 3314 m in the Ness Formation and at 3368 m in the thin Etive Formation. Sampling was attempted also at 3406 and 3406.2 m in the Rannoch Formation, but due to very low permeability no formation fluid was obtained.
    The well was plugged back and classified as an oil and gas appraisal well. West Delta started the sidetrack 34/10-33A 15.12.88 at 18.30 hrs.
    Testing
    Four DST tests were performed in this well.
    DST 1.1 tested the interval 3378 - 3394 m in the Rannoch Formation and produced 289 Sm3 oil and 51000 Sm3 gas /day through a 12.7 mm choke in the main flow. The GOR was 176, the oil density was 0.859 g/cm3, and the gas gravity was 0.680 (air = 1).
    DST 1.2 tested the combined intervals 3378 - 3394 m in the Rannoch Formation plus 3359 - 3374 m in the Ness/Etive Formations and produced 1318 Sm3 oil and 211900 Sm3 gas /day through a 28.6 mm choke in the final flow. The GOR was 161, the oil density was 0.856 g/cm3, and the gas gravity was 0.685 (air = 1). The reservoir temperature measured in the test was ca 123 deg C at reference depth 3373 m.
    DST 2.1 tested the interval 3279 - 3307 m in the Ness Formation and produced 850 Sm3 oil and 376700 Sm3 gas /day through a 19.1 mm choke in the main flow. The GOR was 443, the oil density was 0.850 g/cm3, and the gas gravity was 0.665 (air = 1).
    DST 2.2 tested the combined intervals 3279 - 3307 m and 3311.5 - 3329 m, both within the Ness Formation, and produced 1403 Sm3 oil and 302100 Sm3 gas /day through a 19.1 mm choke in the main flow. The GOR was 215, the oil density was 0.851 g/cm3, and the gas gravity was 0.660 (air = 1). The reservoir temperature measured in the test was ca 122 deg C at reference depth 3301.5 m.

  • 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]
    480.00
    3668.00

  • 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
    2
    3188.0
    3197.0
    [m ]
    3
    3199.0
    3218.7
    [m ]
    4
    3223.0
    3234.7
    [m ]
    5
    3235.0
    3250.9
    [m ]
    6
    3251.0
    3271.0
    [m ]
    7
    3273.5
    3283.2
    [m ]
    8
    3285.5
    3298.0
    [m ]
    9
    3289.5
    3307.6
    [m ]
    10
    3308.0
    3336.0
    [m ]
    11
    3336.0
    3348.9
    [m ]
    12
    3349.5
    3373.0
    [m ]
    13
    3373.0
    3382.5
    [m ]
    14
    3382.5
    3410.3
    [m ]
    15
    3410.5
    3434.9
    [m ]
    16
    3799.0
    3815.7
    [m ]
    17
    3815.5
    3825.9
    [m ]
    18
    3830.0
    3840.0
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    279.7
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 3188-3192m
    Core photo at depth: 3192-3197m
    Core photo at depth: 3199-3202m
    Core photo at depth: 3202-3207m
    Core photo at depth: 3207-3211m
    3188-3192m
    3192-3197m
    3199-3202m
    3202-3207m
    3207-3211m
    Core photo at depth: 3211-3216m
    Core photo at depth: 3216-3218m
    Core photo at depth: 3226-3230m
    Core photo at depth: 3230-3234m
    Core photo at depth: 3235-3239m
    3211-3216m
    3216-3218m
    3226-3230m
    3230-3234m
    3235-3239m
    Core photo at depth: 3239-3243m
    Core photo at depth: 3243-3248m
    Core photo at depth: 3248-3250m
    Core photo at depth: 3250-3254m
    Core photo at depth: 3254-3259m
    3239-3243m
    3243-3248m
    3248-3250m
    3250-3254m
    3254-3259m
    Core photo at depth: 3259-3263m
    Core photo at depth: 3263-3267m
    Core photo at depth: 3267-3271m
    Core photo at depth: 3273-3278m
    Core photo at depth: 3278-3282m
    3259-3263m
    3263-3267m
    3267-3271m
    3273-3278m
    3278-3282m
    Core photo at depth: 3282-3283m
    Core photo at depth: 3285-3289m
    Core photo at depth: 3285-3294m
    Core photo at depth: 3294-3297m
    Core photo at depth: 3297-3302m
    3282-3283m
    3285-3289m
    3285-3294m
    3294-3297m
    3297-3302m
    Core photo at depth: 3302-3306m
    Core photo at depth: 3306-3307m
    Core photo at depth: 3308-3312m
    Core photo at depth: 3312-3316m
    Core photo at depth: 3316-3320m
    3302-3306m
    3306-3307m
    3308-3312m
    3312-3316m
    3316-3320m
    Core photo at depth: 3320-3325m
    Core photo at depth: 3325-3329m
    Core photo at depth: 3329-3333m
    Core photo at depth: 3333-3336m
    Core photo at depth: 3336-3340m
    3320-3325m
    3325-3329m
    3329-3333m
    3333-3336m
    3336-3340m
    Core photo at depth: 3340-3344m
    Core photo at depth: 3344-3348m
    Core photo at depth: 3349-3353m
    Core photo at depth: 3353-3357m
    Core photo at depth: 3357-3362m
    3340-3344m
    3344-3348m
    3349-3353m
    3353-3357m
    3357-3362m
    Core photo at depth: 3362-3366m
    Core photo at depth: 3366-3370m
    Core photo at depth: 3370-3373m
    Core photo at depth: 3373-3377m
    Core photo at depth: 3377-3381m
    3362-3366m
    3366-3370m
    3370-3373m
    3373-3377m
    3377-3381m
    Core photo at depth: 3381-3382m
    Core photo at depth: 3382-3387m
    Core photo at depth: 3387-3391m
    Core photo at depth: 3391-3395m
    Core photo at depth: 3395-3399m
    3381-3382m
    3382-3387m
    3387-3391m
    3391-3395m
    3395-3399m
    Core photo at depth: 3398-3403m
    Core photo at depth: 3403-3407m
    Core photo at depth: 3407-3410m
    Core photo at depth: 3410-3415m
    Core photo at depth: 3415-3418m
    3398-3403m
    3403-3407m
    3407-3410m
    3410-3415m
    3415-3418m
    Core photo at depth: 3418-3423m
    Core photo at depth: 3423-3427m
    Core photo at depth: 3427-3431m
    Core photo at depth: 3431-3434m
    Core photo at depth: 3431-3434m
    3418-3423m
    3423-3427m
    3427-3431m
    3431-3434m
    3431-3434m
    Core photo at depth: 3799-3803m
    Core photo at depth: 3803-3807m
    Core photo at depth: 3807-3811m
    Core photo at depth: 3811-3815m
    Core photo at depth: 3815-3820m
    3799-3803m
    3803-3807m
    3807-3811m
    3811-3815m
    3815-3820m
    Core photo at depth: 3820-3824m
    Core photo at depth: 3824-3828m
    Core photo at depth: 3828-3829m
    Core photo at depth: 3830-3834m
    Core photo at depth: 3834-3838m
    3820-3824m
    3824-3828m
    3828-3829m
    3830-3834m
    3834-3838m
    Core photo at depth: 3838-3840m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    3838-3840m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    3147.5
    [m]
    DC
    GEOCH
    3152.0
    [m]
    C
    GEOCH
    3152.5
    [m]
    C
    GEOCH
    3152.9
    [m]
    C
    GEOCH
    3153.4
    [m]
    C
    GEOCH
    3153.8
    [m]
    C
    GEOCH
    3154.0
    [m]
    C
    GEOCH
    3154.5
    [m]
    C
    GEOCH
    3155.6
    [m]
    C
    GEOCH
    3156.0
    [m]
    C
    GEOCH
    3156.5
    [m]
    C
    GEOCH
    3157.0
    [m]
    C
    GEOCH
    3158.5
    [m]
    C
    GEOCH
    3159.0
    [m]
    C
    GEOCH
    3159.5
    [m]
    C
    GEOCH
    3160.0
    [m]
    C
    GEOCH
    3161.2
    [m]
    C
    GEOCH

  • 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
    TEST1,1
    3378.00
    3394.00
    29.11.1988 - 00:00
    YES
    DST
    TEST2
    0.00
    0.00
    08.12.1988 - 09:00
    YES
    DST
    TEST2,1
    3279.00
    3307.00
    OIL
    08.12.1988 - 07:31
    YES

  • Lithostratigraphy

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.32
    pdf
    0.48
    pdf
    0.34
    pdf
    0.64

  • 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
    3.19
    pdf
    47.33
    pdf
    40.30

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    3378
    3394
    12.7
    1.3
    3359
    3374
    28.6
    2.1
    3279
    3307
    19.1
    2.2
    3279
    3329
    19.1
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    21.000
    1.3
    30.000
    123
    2.1
    32.000
    2.2
    43.500
    122
    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
    288
    51000
    0.854
    0.680
    176
    1.3
    1318
    211900
    0.856
    0.680
    161
    2.1
    850
    376700
    0.850
    0.665
    443
    2.2
    1403
    302100
    0.850
    0.660
    218

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    AC WAVETRAIN
    2831
    3432
    ACDIP GR MISRUN
    0
    0
    CBL VDL GR
    163
    1829
    CBL VDL GR
    2410
    3146
    CBL VDL GR
    2994
    3771
    CDL CN GR
    3771
    3871
    CDL GR CAL
    225
    3150
    DIFL ACL GR
    225
    3150
    DIFL ACL GR
    3771
    3871
    DIFL CDL CN SL
    3146
    3768
    DIPS GR
    2850
    3870
    DLL MLL ACL GR
    3146
    3772
    FMT GR
    3188
    3414
    FMT GR
    3188
    3406
    FMT GR
    3368
    3517
    FMT GR
    3406
    3406
    MWD - SN GR
    231
    3152
    MWD - SN GR
    3161
    3186
    MWD - SN GR
    3435
    3776
    VESLOCITY
    800
    3770

  • 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
    225.0
    36
    226.0
    0.00
    LOT
    SURF.COND.
    20
    459.0
    26
    466.0
    1.43
    LOT
    INTERM.
    13 3/8
    1828.0
    17 1/2
    1844.0
    1.53
    LOT
    INTERM.
    9 5/8
    3148.0
    12 1/4
    3161.0
    1.99
    LOT
    LINER
    7
    3769.0
    8 1/2
    3776.0
    1.96
    LOT
    OPEN HOLE
    3870.0
    6
    3870.0
    0.00

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    470
    1.10
    12.0
    3.0
    WATER BASED
    06.10.1988
    592
    1.10
    12.0
    3.0
    WATER BASED
    07.10.1988
    2153
    1.25
    18.5
    3.5
    WATER BASED
    14.10.1988
    2322
    1.25
    15.0
    3.0
    WATER BASED
    17.10.1988
    2590
    1.25
    18.0
    3.8
    WATER BASED
    17.10.1988
    2709
    1.25
    17.0
    5.5
    WATER BASED
    17.10.1988
    2931
    1.28
    16.0
    4.8
    WATER BASED
    18.10.1988
    3014
    1.34
    18.0
    6.2
    WATER BASED
    19.10.1988
    3111
    1.40
    23.0
    8.6
    WATER BASED
    20.10.1988
    3161
    1.45
    21.0
    6.0
    WATER BASED
    24.10.1988
    3161
    1.45
    18.0
    5.5
    WATER BASED
    24.10.1988
    3174
    1.45
    21.0
    6.0
    WATER BASED
    26.10.1988
    3199
    1.45
    20.0
    4.5
    WATER BASED
    26.10.1988
    3223
    1.49
    21.0
    6.0
    WATER BASED
    27.10.1988
    3251
    1.49
    21.0
    6.0
    WATER BASED
    01.11.1988
    3280
    1.49
    23.0
    7.0
    WATER BASED
    01.11.1988
    3286
    1.53
    21.0
    6.5
    WATER BASED
    01.11.1988
    3293
    1.53
    24.0
    6.0
    WATER BASED
    01.11.1988
    3329
    1.53
    24.0
    7.0
    WATER BASED
    02.11.1988
    3350
    1.53
    24.0
    6.5
    WATER BASED
    02.11.1988
    3377
    1.53
    22.0
    6.0
    WATER BASED
    03.11.1988
    3411
    1.53
    20.0
    6.0
    WATER BASED
    04.11.1988
    3602
    1.53
    75.0
    8.0
    WATER BASED
    07.11.1988
    3619
    1.50
    21.0
    4.0
    WATER BASED
    29.11.1988
    3763
    1.49
    19.0
    5.0
    WATER BASED
    21.11.1988
    3765
    1.50
    23.0
    8.5
    WATER BASED
    11.11.1988
    3766
    1.50
    17.0
    6.5
    WATER BASED
    14.11.1988
    3776
    1.50
    19.0
    8.5
    WATER BASED
    14.11.1988
    3776
    1.50
    19.0
    9.0
    WATER BASED
    14.11.1988
    3776
    1.50
    19.0
    6.5
    WATER BASED
    15.11.1988
    3776
    1.50
    17.0
    6.0
    WATER BASED
    17.11.1988
    3776
    1.50
    21.0
    6.0
    WATER BASED
    21.11.1988
    3776
    1.50
    26.0
    9.0
    WATER BASED
    17.11.1988
    3793
    1.40
    22.0
    6.5
    WATER BASED
    21.11.1988
    3815
    1.40
    23.0
    6.5
    WATER BASED
    22.11.1988
    3831
    1.40
    19.0
    5.0
    WATER BASED
    25.11.1988
    3870
    1.40
    22.0
    5.5
    WATER BASED
    25.11.1988

  • 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
    0.22