Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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21.11.2024 - 01:28
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30/9-4 S

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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.
    30/9-4 S
    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.
    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.
    30/9-4
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    NH 82-064 SP. 444
    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.
    Norsk Hydro Produksjon AS
    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.
    444-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.
    129
    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,
    22.11.1984
    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.
    30.03.1985
    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.
    30.03.1987
    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.
    07.01.2015
    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.
    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.
    25.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    110.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4303.0
    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).
    3577.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    43.4
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    111
    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.
    EIRIKSSON FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    60° 28' 12.83'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 45' 32.05'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6703963.61
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    486742.81
    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.
    452

  • Wellbore history
    General
    Well 30/9-4 S was drilled on the B-structure on the southeast flank of the Oseberg Field in the North Sea. The structure is an elongated rotated fault block bounded by faults in all directions. The Brent Group is truncated by the Base Cretaceous unconformity, and this well was expected to go directly from Cretaceous to the Ness formation. The objectives of the well were to find hydrocarbon accumulations in the Brent Group, secondary in the Statfjord Group. The well was designed to penetrate the Brent Group in a position where the sand in the Ness Formation is preserved. The well was deviated westwards at an angle of approxi­mately 40°.
    Operations and results
    Wildcat well 30/9-4 S was spudded with the semi-submersible installation Treasure Seeker on 22 November 1984 and drilled to TD at 4303 m (3577 m TVD) in the Early Jurassic Eiriksson Formation. No significant problems were encountered during operations. The well was drilled with spud mud down to 222 m, with seawater/gel from 222 m to 630 m, with oil based Safemul mud from 630 m to 3297 m, with NaCl/polymer mud from 3297 m to 3680 m, and with oil based Safemul mud from 3680 m to TD.
    The well 30/9-4 encountered two separate hydrocarbon reservoirs in the Middle Jurassic Brent Group. Pressure data indicated no communication between the two hydrocarbon columns. The Tarbert Formation and uppermost Ness Formation (3295-3379 m, 2773-2841 m TVD) sandstones were found to be gas bearing, but no definite gas/fluid contacts were evident. Net pay in the gas zone was calculated to be 27.6 m (22.1 m TVD), average porosity 18.6%, and the average water saturation 20.9%. The Ness Formation (3379-3551 m, 2841-2979 m TVD) proved to be oil bearing, but again no OWC could be discerned. Net pay in the oil zone was calculated to be 10.9 m (8.8 m TVD), average porosity to 22.2% and the average water saturation to 33.2%. The Statfjord Group was water bearing. No oil shows were reported above or below the hydrocarbon bearing Brent reservoir sands.
    Thirteen conventional cores were cut in the well. Cores no. 1-3 (3332 - 3381 m) and 4-11 (3432-3500 m) were cut in the gas bearing and oil bearing Brent Group sections, respectively. Core no. 12 (3580-3598.1 m) was cut in the Oseberg Formation and core no. 13 (4268-4277 m) was cut in the Eiriksson Formation. RFT fluid samples were taken in the Brent Group at 3319.5 m (oil and gas), 3421 m (condensate and gas), and in the top of the water bearing Statfjord Group at 4207.2 m.
    The well was permanently abandoned on 30 March 1985 as an oil and gas discovery.
    Testing
    Two drill stem tests were performed in the Brent Group.
    DST 1 tested the interval 3416.9 to 3422.9 m (2871.4 m to 2876.1 m TVD) in the oil bearing part of the Ness Formation. The well produced 783.2 Sm3 oil and 158600 Sm3 gas/day through a 72/64" choke. The GOR was 202.5 Sm3/Sm3. The oil gravity was 41.8 °API and the gas gravity was 0.8 (air=l). The bottom hole temperature was 111.1°C. The test produced 2.2% C02 and no H2S.
    DST 2 tested the interval 3311.3 to 3324.3 m (2787 to 2797.7 m TVD) in the gas bearing Tarbert Formation. It produced 1130000 Sm3 gas and 333.9 Sm3 condensate/day through a 64/64" choke. The GOR was 3384.3 Sm3/Sm3. The oil gravity was 55.7 °API and the gas gravity was 0.7 (air=l). The bottom hole temperature was 108.3°C. The test produced 1.5% C02 and 0.8 ppm H2S.

  • 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]
    230.00
    4300.00

  • 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
    3332.0
    3350.3
    [m ]
    2
    3350.6
    3368.0
    [m ]
    3
    3368.6
    3379.0
    [m ]
    4
    3432.4
    3436.0
    [m ]
    5
    3437.0
    3444.5
    [m ]
    6
    3445.0
    3466.2
    [m ]
    7
    3457.0
    3462.7
    [m ]
    8
    3467.0
    3469.6
    [m ]
    9
    3472.0
    3474.7
    [m ]
    10
    3475.0
    3483.8
    [m ]
    11
    3484.0
    3498.1
    [m ]
    12
    3580.0
    3598.0
    [m ]
    13
    4268.0
    4276.3
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    138.6
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 3332-3336m
    Core photo at depth: 3336-3340m
    Core photo at depth: 3340-3344m
    Core photo at depth: 3344-3348m
    Core photo at depth: 3348-3351m
    3332-3336m
    3336-3340m
    3340-3344m
    3344-3348m
    3348-3351m
    Core photo at depth: 3351-3355m
    Core photo at depth: 3355-3359m
    Core photo at depth: 3359-3362m
    Core photo at depth: 3363-3367m
    Core photo at depth: 3367-3369m
    3351-3355m
    3355-3359m
    3359-3362m
    3363-3367m
    3367-3369m
    Core photo at depth: 3370-3373m
    Core photo at depth: 3374-3377m
    Core photo at depth: 3378-3434m
    Core photo at depth: 3434-3438m
    Core photo at depth: 3438-3442m
    3370-3373m
    3374-3377m
    3378-3434m
    3434-3438m
    3438-3442m
    Core photo at depth: 3442-3446m
    Core photo at depth: 3446-3450m
    Core photo at depth: 3450-3454m
    Core photo at depth: 3454-3459m
    Core photo at depth: 3459-3462m
    3442-3446m
    3446-3450m
    3450-3454m
    3454-3459m
    3459-3462m
    Core photo at depth: 3467-3473m
    Core photo at depth: 3473-3477m
    Core photo at depth: 3477-3481m
    Core photo at depth: 3481-3485m
    Core photo at depth: 3485-3489m
    3467-3473m
    3473-3477m
    3477-3481m
    3481-3485m
    3485-3489m
    Core photo at depth: 3489-3493m
    Core photo at depth: 3393-3397m
    Core photo at depth: 3497-3582m
    Core photo at depth: 3497-3582m
    Core photo at depth: 3582-3586m
    3489-3493m
    3393-3397m
    3497-3582m
    3497-3582m
    3582-3586m
    Core photo at depth: 3586-3590m
    Core photo at depth: 3590-3594m
    Core photo at depth: 3594-3598m
    Core photo at depth: 4268-4272m
    Core photo at depth: 4272-4276m
    3586-3590m
    3590-3594m
    3594-3598m
    4268-4272m
    4272-4276m
    Core photo at depth: 4276-4276m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    4276-4276m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    2550.0
    [m]
    DC
    RRI
    2565.0
    [m]
    DC
    RRI
    3232.0
    [m]
    DC
    RRI
    3252.0
    [m]
    DC
    RRI
    3315.0
    [m]
    DC
    RRI
    3330.0
    [m]
    DC
    RRI
    3345.0
    [m]
    DC
    RRI
    3364.2
    [m]
    C
    RRI
    3395.0
    [m]
    DC
    RRI
    3412.0
    [m]
    DC
    RRI
    3417.0
    [m]
    DC
    RRI
    3432.0
    [m]
    DC
    RRI
    3432.6
    [m]
    C
    RRI
    3443.1
    [m]
    C
    RRI
    3452.8
    [m]
    C
    RRI
    3458.6
    [m]
    C
    RRI
    3467.8
    [m]
    C
    RRI
    3480.8
    [m]
    C
    RRI
    3498.1
    [m]
    C
    RRI
    3510.0
    [m]
    DC
    RRI
    3525.0
    [m]
    DC
    RRI
    3540.0
    [m]
    DC
    RRI
    3555.0
    [m]
    DC
    RRI
    3570.0
    [m]
    DC
    RRI
    3634.0
    [m]
    SWC
    RRI
    3665.0
    [m]
    DC
    RRI
    3680.0
    [m]
    DC
    RRI
    3935.0
    [m]
    DC
    RRI
    3950.0
    [m]
    DC
    RRI
    3960.0
    [m]
    DC
    RRI
    3974.0
    [m]
    SWC
    RRI
    3977.0
    [m]
    DC
    RRI
    3990.0
    [m]
    DC
    RRI
    4003.0
    [m]
    SWC
    RRI
    4005.0
    [m]
    DC
    RRI
    4020.0
    [m]
    DC
    RRI
    4025.0
    [m]
    SWC
    RRI
    4035.0
    [m]
    DC
    RRI
    4045.0
    [m]
    SWC
    RRI
    4050.0
    [m]
    SWC
    RRI
    4050.0
    [m]
    DC
    RRI
    4064.0
    [m]
    SWC
    RRI
    4065.0
    [m]
    DC
    RRI
    4080.0
    [m]
    SWC
    RRI
    4080.0
    [m]
    DC
    RRI
    4082.0
    [m]
    DC
    RRI
    4088.0
    [m]
    SWC
    RRI
    4097.0
    [m]
    DC
    RRI
    4115.0
    [m]
    SWC
    RRI
    4130.0
    [m]
    SWC
    RRI
    4139.0
    [m]
    SWC
    RRI
    4149.0
    [m]
    SWC
    RRI
    4162.0
    [m]
    SWC
    RRI
    4174.5
    [m]
    SWC
    RRI
    4268.3
    [m]
    C
    RRI
    4276.5
    [m]
    C
    RRI
    4287.0
    [m]
    DC
    RRI
    4292.0
    [m]
    SWC
    RRI
    4302.0
    [m]
    SWC
    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
    DST1
    3422.00
    3416.00
    OIL
    11.03.1985 - 00:00
    YES
    DST
    DST2
    3324.00
    3311.00
    CONDENSATE
    20.03.1985 - 00:00
    YES

  • Lithostratigraphy

  • 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
    6.42
    pdf
    30.68

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    3417
    3423
    28.6
    2.0
    3311
    3324
    25.0
    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
    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
    783
    158000
    0.800
    0.800
    2025
    2.0
    334
    1100000
    0.800
    0.700
    3384

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL VDL GR CCL
    272
    1648
    CBL VDL GR CCL
    1200
    3261
    CBL VDL GR CCL
    3167
    3475
    CET GR
    1200
    3261
    CET GR
    3167
    3475
    CST
    2739
    3285
    CST
    3307
    4080
    CST
    4088
    4307
    DIL LSS GR
    618
    4304
    DLL MSFL GR CAL
    3281
    3677
    HDT
    3281
    4305
    ISF LSS GR MSFL
    221
    3679
    LDL GR CAL CNL
    618
    4305
    NGT SDT
    3272
    4305
    RFT
    3296
    3626
    RFT
    3319
    0
    RFT
    3595
    4259
    RFT
    4207
    0
    SHDT
    3281
    3681
    VSP
    1624
    4307

  • 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
    221.0
    36
    222.0
    0.00
    LOT
    SURF.COND.
    20
    619.0
    26
    630.0
    1.40
    LOT
    INTERM.
    13 3/8
    1648.0
    17 1/2
    1667.0
    1.66
    LOT
    INTERM.
    9 5/8
    3275.0
    12 1/4
    3297.0
    1.75
    LOT
    LINER
    7
    3553.0
    8 1/2
    4303.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    34
    1.27
    19.0
    5.0
    WATER BASED
    22.01.1985
    222
    0.00
    WATERBASED
    26.11.1984
    617
    1.09
    44.0
    7.0
    WATERBASED
    26.11.1984
    617
    1.09
    44.0
    7.0
    WATER BASED
    26.11.1984
    625
    1.10
    6.0
    15.0
    WATERBASED
    26.11.1984
    625
    1.10
    6.0
    15.0
    WATER BASED
    26.11.1984
    630
    1.11
    6.0
    16.0
    WATER BASED
    27.11.1984
    630
    1.10
    6.0
    16.0
    WATER BASED
    28.11.1984
    630
    1.07
    13.0
    4.0
    WATER BASED
    04.12.1984
    630
    1.15
    14.0
    4.0
    WATER BASED
    04.12.1984
    630
    0.00
    WATERBASED
    29.11.1984
    630
    1.11
    6.0
    16.0
    WATERBASED
    27.11.1984
    630
    0.00
    6.0
    16.0
    WATERBASED
    28.11.1984
    630
    0.00
    13.0
    4.0
    WATERBASED
    04.12.1984
    630
    0.00
    14.0
    4.0
    WATERBASED
    04.12.1984
    700
    1.15
    14.0
    4.5
    WATERBASED
    04.12.1984
    700
    1.15
    14.0
    4.5
    WATER BASED
    04.12.1984
    885
    1.15
    17.0
    9.0
    WATER BASED
    05.12.1984
    885
    1.15
    17.0
    9.0
    WATERBASED
    05.12.1984
    1076
    1.15
    20.0
    8.5
    WATERBASED
    06.12.1984
    1076
    1.15
    20.0
    8.5
    WATER BASED
    06.12.1984
    1227
    1.15
    20.0
    10.5
    WATER BASED
    07.12.1984
    1227
    1.15
    20.0
    10.5
    WATERBASED
    07.12.1984
    1354
    1.15
    23.0
    12.0
    WATERBASED
    11.12.1984
    1354
    1.15
    23.0
    12.0
    WATER BASED
    11.12.1984
    1444
    1.15
    22.0
    11.0
    WATER BASED
    11.12.1984
    1444
    1.15
    22.0
    11.0
    WATERBASED
    11.12.1984
    1581
    1.15
    23.0
    15.0
    WATERBASED
    11.12.1984
    1581
    1.15
    23.0
    15.0
    WATER BASED
    11.12.1984
    1667
    1.18
    25.0
    15.0
    WATER BASED
    11.12.1984
    1667
    1.25
    31.0
    11.0
    OIL BASED
    13.12.1984
    1667
    1.27
    37.0
    13.5
    OIL BASED
    16.12.1984
    1667
    1.05
    46.0
    15.0
    OIL BASED
    16.12.1984
    1667
    1.50
    42.0
    16.0
    OIL BASED
    16.12.1984
    1667
    1.25
    31.0
    11.0
    OIL BASED
    13.12.1984
    1667
    0.00
    46.0
    15.0
    OIL BASED
    15.12.1984
    1667
    1.18
    25.0
    15.0
    WATERBASED
    11.12.1984
    1667
    1.20
    26.0
    12.5
    OIL BASED
    11.12.1984
    1667
    0.00
    37.0
    13.5
    OIL BASED
    15.12.1984
    1667
    0.00
    42.0
    16.0
    OIL BASED
    15.12.1984
    1837
    1.50
    33.0
    11.5
    OIL BASED
    19.12.1984
    1837
    1.50
    33.0
    11.5
    OIL BASED
    18.12.1984
    2067
    1.50
    38.0
    14.0
    OIL BASED
    20.12.1984
    2211
    1.50
    39.0
    11.0
    OIL BASED
    20.12.1984
    2402
    1.50
    31.0
    10.0
    OIL BASED
    26.12.1984
    2460
    1.50
    34.0
    10.5
    OIL BASED
    26.12.1984
    2477
    1.50
    36.0
    12.0
    OIL BASED
    26.12.1984
    2576
    1.50
    39.0
    14.0
    OIL BASED
    26.12.1984
    2693
    1.50
    42.0
    17.0
    OIL BASED
    26.12.1984
    2738
    1.50
    45.0
    18.0
    OIL BASED
    26.12.1984
    2780
    1.51
    42.0
    16.0
    OIL BASED
    27.12.1984
    2921
    1.50
    45.0
    18.0
    OIL BASED
    01.01.1985
    3087
    1.50
    43.0
    15.0
    OIL BASED
    01.01.1985
    3117
    1.31
    32.0
    5.0
    OIL BASED
    24.03.1985
    3151
    1.50
    39.0
    16.0
    OIL BASED
    01.01.1985
    3253
    1.50
    42.0
    16.0
    OIL BASED
    01.01.1985
    3297
    1.27
    20.0
    6.5
    WATER BASED
    06.01.1985
    3297
    1.50
    40.0
    17.0
    OIL BASED
    02.01.1985
    3297
    1.50
    40.0
    17.0
    OIL BASED
    03.01.1985
    3297
    1.50
    40.0
    17.0
    OIL BASED
    06.01.1985
    3297
    1.27
    20.0
    6.5
    WATER BASED
    06.01.1985
    3297
    1.50
    39.0
    16.0
    OIL BASED
    01.01.1985
    3297
    1.50
    40.0
    17.0
    OIL BASED
    02.01.1985
    3297
    1.50
    40.0
    17.0
    OIL BASED
    03.01.1985
    3297
    1.50
    40.0
    17.0
    OIL BASED
    06.01.1985
    3301
    1.27
    19.0
    7.5
    WATER BASED
    06.01.1985
    3324
    1.27
    23.0
    4.0
    OIL BASED
    21.03.1985
    3340
    1.27
    20.0
    8.0
    WATER BASED
    07.01.1985
    3348
    1.27
    29.0
    5.0
    OIL BASED
    24.03.1985
    3348
    1.29
    31.0
    4.5
    OIL BASED
    24.03.1985
    3348
    1.27
    25.0
    5.0
    OIL BASED
    18.03.1985
    3348
    1.27
    24.0
    5.0
    OIL BASED
    19.03.1985
    3348
    1.27
    25.0
    4.0
    OIL BASED
    20.03.1985
    3348
    1.27
    24.0
    5.0
    OIL BASED
    19.03.1985
    3348
    1.27
    25.0
    4.0
    OIL BASED
    20.03.1985
    3348
    1.27
    29.0
    5.0
    OIL BASED
    24.03.1985
    3348
    1.29
    31.0
    4.5
    OIL BASED
    24.03.1985
    3350
    1.28
    47.0
    8.0
    OIL BASED
    17.03.1985
    3350
    1.27
    34.0
    6.0
    OIL BASED
    17.03.1985
    3350
    1.28
    33.0
    7.0
    OIL BASED
    17.03.1985
    3350
    1.28
    33.0
    7.0
    OIL BASED
    17.03.1985
    3350
    1.28
    47.0
    8.0
    OIL BASED
    17.03.1985
    3368
    1.27
    23.0
    9.0
    WATER BASED
    07.01.1985
    3387
    1.27
    21.0
    8.0
    WATER BASED
    07.01.1985
    3432
    1.27
    25.0
    11.0
    WATER BASED
    10.01.1985
    3445
    1.27
    24.0
    10.0
    WATER BASED
    14.01.1985
    3457
    1.27
    22.0
    5.5
    WATER BASED
    21.01.1985
    3457
    1.27
    17.0
    5.5
    WATER BASED
    14.01.1985
    3457
    1.27
    18.0
    6.0
    WATER BASED
    15.01.1985
    3457
    1.27
    20.0
    7.0
    WATER BASED
    16.01.1985
    3457
    1.27
    19.0
    8.0
    WATER BASED
    18.01.1985
    3457
    1.27
    19.0
    7.0
    WATER BASED
    21.01.1985
    3457
    1.27
    22.0
    5.5
    WATER BASED
    21.01.1985
    3457
    1.27
    20.0
    7.5
    WATER BASED
    14.01.1985
    3457
    1.27
    17.0
    5.5
    WATER BASED
    14.01.1985
    3457
    1.27
    18.0
    6.0
    WATER BASED
    15.01.1985
    3457
    1.27
    20.0
    7.0
    WATER BASED
    16.01.1985
    3457
    1.27
    19.0
    7.5
    WATER BASED
    17.01.1985
    3457
    1.27
    19.0
    8.0
    WATER BASED
    18.01.1985
    3457
    1.27
    19.0
    7.0
    WATER BASED
    21.01.1985
    3457
    1.27
    19.0
    7.5
    WATER BASED
    17.01.1985
    3467
    1.28
    21.0
    6.0
    WATER BASED
    21.01.1985
    3472
    1.27
    21.0
    5.0
    WATER BASED
    21.01.1985
    3500
    1.27
    18.0
    5.0
    WATER BASED
    23.01.1985
    3545
    1.31
    39.0
    12.0
    OIL BASED
    25.02.1985
    3545
    1.27
    29.0
    65.0
    OIL BASED
    25.02.1985
    3545
    1.27
    31.0
    6.0
    OIL BASED
    26.02.1985
    3545
    1.27
    20.0
    5.0
    OIL BASED
    27.02.1985
    3545
    1.27
    23.0
    5.0
    OIL BASED
    01.03.1985
    3545
    1.27
    24.0
    5.0
    OIL BASED
    03.03.1985
    3545
    1.27
    25.0
    5.0
    OIL BASED
    03.03.1985
    3545
    1.27
    23.0
    6.0
    OIL BASED
    04.03.1985
    3545
    1.27
    23.0
    6.0
    OIL BASED
    05.03.1985
    3545
    1.27
    23.0
    6.0
    OIL BASED
    06.03.1985
    3545
    1.27
    29.0
    6.5
    OIL BASED
    08.03.1985
    3545
    1.27
    25.0
    6.0
    OIL BASED
    10.03.1985
    3545
    1.27
    33.0
    8.0
    OIL BASED
    10.03.1985
    3545
    1.27
    24.0
    5.5
    OIL BASED
    10.03.1985
    3545
    1.27
    24.0
    6.0
    OIL BASED
    12.03.1985
    3545
    1.27
    24.0
    6.0
    OIL BASED
    13.03.1985
    3545
    1.27
    36.0
    6.0
    OIL BASED
    14.03.1985
    3545
    1.27
    31.0
    6.0
    OIL BASED
    26.02.1985
    3545
    1.27
    20.0
    5.0
    OIL BASED
    27.02.1985
    3545
    1.27
    23.0
    5.0
    OIL BASED
    01.03.1985
    3545
    1.27
    24.0
    5.0
    OIL BASED
    03.03.1985
    3545
    1.27
    25.0
    5.0
    OIL BASED
    03.03.1985
    3545
    1.27
    23.0
    6.0
    OIL BASED
    04.03.1985
    3545
    1.27
    23.0
    6.0
    OIL BASED
    05.03.1985
    3545
    1.27
    23.0
    6.0
    OIL BASED
    06.03.1985
    3545
    1.27
    29.0
    6.5
    OIL BASED
    08.03.1985
    3545
    1.27
    25.0
    6.0
    OIL BASED
    10.03.1985
    3545
    1.27
    33.0
    8.0
    OIL BASED
    10.03.1985
    3545
    1.27
    24.0
    5.5
    OIL BASED
    10.03.1985
    3545
    1.27
    24.0
    55.0
    OIL BASED
    11.03.1985
    3545
    1.27
    24.0
    6.0
    OIL BASED
    12.03.1985
    3545
    1.27
    36.0
    6.0
    OIL BASED
    14.03.1985
    3545
    1.27
    29.0
    65.0
    OIL BASED
    25.02.1985
    3545
    1.27
    24.0
    6.0
    OIL BASED
    13.03.1985
    3545
    1.27
    24.0
    55.0
    OIL BASED
    11.03.1985
    3558
    1.27
    20.0
    6.0
    WATER BASED
    24.01.1985
    3580
    1.27
    21.0
    6.5
    WATER BASED
    29.01.1985
    3680
    1.27
    33.0
    12.5
    OIL BASED
    04.02.1985
    3680
    1.27
    33.0
    12.5
    OIL BASED
    04.02.1985
    3680
    1.27
    22.0
    6.5
    WATER BASED
    04.02.1985
    3871
    1.27
    27.0
    13.0
    OIL BASED
    04.02.1985
    3972
    1.27
    28.0
    12.0
    OIL BASED
    05.02.1985
    4046
    1.27
    26.0
    11.0
    OIL BASED
    06.02.1985
    4120
    1.27
    31.0
    11.0
    OIL BASED
    07.02.1985
    4120
    1.27
    35.0
    11.0
    OIL BASED
    08.02.1985
    4120
    1.27
    35.0
    11.0
    OIL BASED
    08.02.1985
    4166
    1.27
    30.0
    10.0
    OIL BASED
    10.02.1985
    4189
    1.27
    31.0
    11.0
    OIL BASED
    10.02.1985
    4189
    1.27
    31.0
    10.5
    OIL BASED
    10.02.1985
    4189
    1.27
    31.0
    10.5
    OIL BASED
    10.02.1985
    4228
    1.27
    37.0
    10.0
    OIL BASED
    12.02.1985
    4268
    1.27
    32.0
    10.0
    OIL BASED
    12.02.1985
    4277
    1.27
    30.0
    9.0
    OIL BASED
    13.02.1985
    4303
    1.27
    35.0
    9.0
    OIL BASED
    18.02.1985
    4303
    1.27
    35.0
    10.0
    OIL BASED
    17.02.1985
    4303
    1.27
    36.0
    10.0
    OIL BASED
    17.02.1985
    4303
    1.27
    35.0
    9.0
    OIL BASED
    17.02.1985
    4303
    1.27
    35.0
    9.0
    OIL BASED
    18.02.1985
    4303
    1.27
    36.0
    10.0
    OIL BASED
    19.02.1985
    4303
    1.27
    37.0
    11.0
    OIL BASED
    21.02.1985
    4303
    1.29
    38.0
    11.0
    OIL BASED
    21.02.1985
    4303
    1.27
    31.0
    10.0
    OIL BASED
    14.02.1985
    4303
    1.27
    35.0
    10.0
    OIL BASED
    17.02.1985
    4303
    1.27
    36.0
    10.0
    OIL BASED
    17.02.1985
    4303
    1.27
    35.0
    9.0
    OIL BASED
    17.02.1985
    4303
    1.27
    36.0
    10.0
    OIL BASED
    19.02.1985
    4303
    1.27
    37.0
    11.0
    OIL BASED
    21.02.1985
    4303
    1.29
    38.0
    11.0
    OIL BASED
    21.02.1985

  • 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
    0.23