Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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29.04.2024 - 01:33
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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.
    1/2-1
    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.
    1/2-1
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    PW 8303A - 10 SP. 290
    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.
    Phillips Petroleum Norsk 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.
    604-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.
    77
    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,
    20.03.1989
    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.
    04.06.1989
    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.
    04.06.1991
    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.
    19.12.2007
    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
    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.
    PALEOCENE
    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.
    FORTIES 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.
    72.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3574.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    2
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    147
    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.
    CAMPANIAN
    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.
    TOR FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    56° 53' 15.07'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 28' 35.7'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6305128.26
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    468106.29
    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.
    1382

  • Wellbore history
    General
    Well 1/2-1 is located in the Central Graben, about 200 m from the UK border in the North Sea. The main objective was Paleocene sands of the Rogaland Group. The secondary target was the chalk formations, although these were possibly not enough fractured to represent a reservoir.
    Operations and results
    Wildcat well 1/2-1 was spudded with the semi-submersible installation Ross Isle on 20 March 1989 and drilled to TD at 3574 m in the Late Cretaceous Tor Formation. While cutting of core no 7, the elevators accidentally opened and dropped the string. Two attempts were made to recover the string with no success. The hole was sidetracked from 3078.5 m and core no 8 was cut. The well was drilled with seawater down to 645 m, with native mud (water mixed with clays from the borehole itself) from 645 m to1525 m, and with seawater from 1525 m to TD. No shallow gas was detected in the hole.
    The Forties Formation came in at 3121 m. The formation was hydrocarbon bearing down to 3142.5 m as confirmed by both electric logs and the RFT pressure gradient. The reservoir sandstones of the Forties Formation showed good to excellent reservoir properties. Average core porosity was 18.5% and test permeability was measured to 49 mD.
    Shows on cores were recorded down to core # 8 where they gradually decreased to zero at 3166 m. From the RFT data two water gradients were identified below the oil zone. A shift of 8 psi between them suggested the existence of an impermeable barrier around 3160.2 and 3162 m. Core saturations and fluorescence indicated the potential existence of a thin (4 m) oil zone below this barrier. This zone was not identified from the logs and was not evaluated for a test due to lack of data at that point.
    The Ekofisk formation was encountered at 3407 m, and the Tor formation at 3514 m. Both formations were water bearing.
    A total of 8 cores were cut in the Forties Formation, seven in the first hole and the eighth in the sidetrack. No wire line fluid samples were taken.
    The well was permanently abandoned on 4 June 1989 as an oil/gas discovery.
    Testing
    Two intervals were perforated and tested with the intention to first test the oil zone and then open up a deeper zone to produce and sample formation water. The perforated intervals were 3122 - 3137 m in the oil zone and 3145.5 - 3157.7 m in the water zone. The oil test produced up to 859 Sm3 oil and 57200 Sm3 gas/day on a 64/64" choke. The GOR was 67 Sm3/Sm3 and the oil gravity was 42.5 deg API. The maximum temperature recorded during the test was 133.8 deg C. Analysis of the final co-mingled oil + water test confirmed that the lower perforation interval produced only water. This confirmed the contact at 3142.5 m to be an OWC.

  • 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]
    658.36
    3573.78

  • 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
    10208.0
    10208.4
    [ft ]
    2
    10216.0
    10233.0
    [ft ]
    4
    10256.0
    10286.0
    [ft ]
    5
    10286.0
    10358.0
    [ft ]
    6
    10358.0
    10364.6
    [ft ]
    7
    10368.0
    10377.6
    [ft ]
    8
    10368.0
    10395.3
    [ft ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    49.7
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 10208-10228ft
    Core photo at depth: 19228-10262ft
    Core photo at depth: 10262-10277ft
    Core photo at depth: 10277-10292ft
    Core photo at depth: 10292-10307ft
    10208-10228ft
    19228-10262ft
    10262-10277ft
    10277-10292ft
    10292-10307ft
    Core photo at depth: 10307-10322ft
    Core photo at depth: 10322-10337ft
    Core photo at depth: 10337-10352ft
    Core photo at depth: 10352-10364ft
    Core photo at depth: 10368-10377ft
    10307-10322ft
    10322-10337ft
    10337-10352ft
    10352-10364ft
    10368-10377ft
    Core photo at depth: 10368-10383ft
    Core photo at depth: 10383-10395ft
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    10368-10383ft
    10383-10395ft

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    3163.1
    [m]
    C
    HYDRO
    8880.0
    [ft]
    DC
    SSI
    8940.0
    [ft]
    DC
    SSI
    9000.0
    [ft]
    DC
    SSI
    9060.0
    [ft]
    DC
    SSI
    9120.0
    [ft]
    DC
    SSI
    9180.0
    [ft]
    DC
    SSI
    9240.0
    [ft]
    DC
    SSI
    9300.0
    [ft]
    DC
    SSI
    9363.0
    [ft]
    SWC
    SSI
    9420.0
    [ft]
    DC
    SSI
    9480.0
    [ft]
    DC
    SSI
    9540.0
    [ft]
    DC
    SSI
    9585.0
    [ft]
    SWC
    SSI
    9600.0
    [ft]
    DC
    SSI
    9660.0
    [ft]
    DC
    SSI
    9684.0
    [ft]
    SWC
    SSI
    9720.0
    [ft]
    DC
    SSI
    9780.0
    [ft]
    DC
    SSI
    9840.0
    [ft]
    DC
    SSI
    9900.0
    [ft]
    DC
    SSI
    9930.0
    [ft]
    DC
    SSI
    9960.0
    [ft]
    SWC
    SSI
    9990.0
    [ft]
    SWC
    SSI
    10020.0
    [ft]
    DC
    SSI
    10050.0
    [ft]
    DC
    SSI
    10080.0
    [ft]
    DC
    SSI
    10110.0
    [ft]
    DC
    SSI
    10140.0
    [ft]
    DC
    SSI
    10170.0
    [ft]
    DC
    SSI
    10200.0
    [ft]
    DC
    SSI
    10229.9
    [ft]
    C
    SSI
    10276.3
    [ft]
    C
    SSI
    10308.6
    [ft]
    C
    SSI
    10339.3
    [ft]
    C
    SSI
    10362.0
    [ft]
    C
    SSI
    10369.3
    [ft]
    C
    SSI
    10400.0
    [ft]
    DC
    SSI
    10460.0
    [ft]
    DC
    SSI
    10490.0
    [ft]
    DC
    SSI
    10520.0
    [ft]
    DC
    SSI
    10580.0
    [ft]
    DC
    SSI
    10640.0
    [ft]
    DC
    SSI
    10700.0
    [ft]
    DC
    SSI
    10744.0
    [ft]
    SWC
    SSI
    10780.0
    [ft]
    DC
    SSI
    10810.0
    [ft]
    DC
    SSI
    10850.0
    [ft]
    SWC
    SSI
    10880.0
    [ft]
    SWC
    SSI
    10910.0
    [ft]
    DC
    SSI
    10940.0
    [ft]
    DC
    SSI
    10970.0
    [ft]
    DC
    SSI
    11000.0
    [ft]
    DC
    SSI
    11030.0
    [ft]
    DC
    SSI
    11060.0
    [ft]
    DC
    SSI
    11091.0
    [ft]
    SWC
    SSI

  • 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
    3122.30
    3137.00
    27.05.1989 - 06:00
    YES

  • Lithostratigraphy
    Lithostratigraphy
    Top depth [mMD RKB]
    Lithostrat. unit
    94
    1777
    3059
    3059
    3121
    3275
    3335
    3407
    3407
    3514

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.17
    pdf
    3.41

  • 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
    1.76
    pdf
    155.63

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    3122
    3137
    25.4
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    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
    859
    57000
    0.810
    66

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CST GR
    666
    3557
    DIL SLS GR
    645
    3052
    DLL MSFL GR
    3052
    3572
    FMS GR
    3052
    3576
    LDL CNL NGT
    645
    3575
    MWD - GR RES DIR
    308
    5023
    RFT GR
    3059
    3208
    SLS GR
    3052
    3573
    TEST
    1
    2
    TEST
    2
    3
    TEST4
    0
    0
    VSP
    631
    3468

  • 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
    170.0
    36
    171.0
    0.00
    LOT
    INTERM.
    20
    645.0
    26
    648.0
    1.69
    LOT
    INTERM.
    13 3/8
    1524.0
    17 1/2
    1531.0
    1.82
    LOT
    INTERM.
    9 5/8
    3052.0
    12 1/4
    3056.0
    1.88
    LOT
    LINER
    7
    3569.0
    8 1/2
    3576.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    171
    1.04
    WATER BASED
    29.03.1989
    279
    1.04
    WATER BASED
    29.03.1989
    546
    1.04
    WATER BASED
    29.03.1989
    564
    1.04
    WATER BASED
    29.03.1989
    648
    1.04
    WATER BASED
    29.03.1989
    650
    1.04
    WATER BASED
    29.03.1989
    651
    1.05
    14.0
    5.7
    WATER BASED
    30.03.1989
    1197
    1.16
    62.0
    1.9
    WATER BASED
    31.03.1989
    1531
    1.44
    21.0
    3.4
    WATER BASED
    04.04.1989
    1531
    1.44
    8.0
    16.3
    WATER BASED
    03.04.1989
    1531
    1.44
    9.0
    14.4
    WATER BASED
    03.04.1989
    1531
    1.44
    35.0
    3.8
    WATER BASED
    03.04.1989
    1783
    1.44
    20.0
    3.8
    WATER BASED
    05.04.1989
    2199
    1.50
    23.0
    10.5
    WATER BASED
    06.04.1989
    2504
    1.53
    20.0
    9.6
    WATER BASED
    07.04.1989
    2906
    1.58
    19.0
    11.0
    WATER BASED
    10.04.1989
    3050
    1.62
    11.0
    7.7
    WATER BASED
    10.04.1989
    3056
    1.62
    15.0
    7.7
    WATER BASED
    11.04.1989
    3056
    1.62
    15.0
    7.7
    WATER BASED
    11.04.1989
    3056
    1.64
    11.0
    5.7
    WATER BASED
    12.04.1989
    3056
    1.64
    13.0
    5.7
    WATER BASED
    14.04.1989
    3056
    1.64
    13.0
    4.8
    WATER BASED
    17.04.1989
    3056
    1.64
    13.0
    4.8
    WATER BASED
    17.04.1989
    3056
    1.64
    13.0
    4.8
    WATER BASED
    17.04.1989
    3056
    1.62
    14.0
    7.2
    WATER BASED
    10.04.1989
    3056
    1.64
    12.0
    5.7
    WATER BASED
    13.04.1989
    3059
    1.61
    18.0
    6.2
    WATER BASED
    27.04.1989
    3071
    1.61
    15.0
    4.8
    WATER BASED
    26.04.1989
    3109
    1.64
    16.0
    8.1
    WATER BASED
    17.04.1989
    3109
    1.64
    16.0
    8.1
    WATER BASED
    17.04.1989
    3109
    1.64
    14.0
    7.7
    WATER BASED
    17.04.1989
    3109
    1.64
    14.0
    7.7
    WATER BASED
    17.04.1989
    3109
    1.64
    16.0
    8.1
    WATER BASED
    17.04.1989
    3109
    1.64
    14.0
    7.7
    WATER BASED
    17.04.1989
    3114
    1.64
    16.0
    7.2
    WATER BASED
    19.04.1989
    3117
    1.61
    18.0
    6.7
    WATER BASED
    28.04.1989
    3125
    1.64
    19.0
    8.1
    WATER BASED
    19.04.1989
    3126
    1.63
    19.0
    6.7
    WATER BASED
    20.04.1989
    3144
    1.61
    21.0
    4.8
    WATER BASED
    02.05.1989
    3154
    1.62
    20.0
    5.7
    WATER BASED
    21.04.1989
    3160
    1.61
    21.0
    6.7
    WATER BASED
    24.04.1989
    3160
    1.61
    21.0
    6.7
    WATER BASED
    02.05.1989
    3164
    1.61
    18.0
    6.2
    WATER BASED
    24.04.1989
    3164
    1.61
    18.0
    5.7
    WATER BASED
    24.04.1989
    3164
    1.61
    19.0
    5.7
    WATER BASED
    26.04.1989
    3170
    1.61
    22.0
    6.2
    WATER BASED
    02.05.1989
    3185
    1.09
    6.0
    5.3
    WATER BASED
    22.05.1989
    3247
    1.58
    23.0
    6.2
    WATER BASED
    02.05.1989
    3320
    1.56
    22.0
    5.3
    WATER BASED
    03.05.1989
    3361
    1.57
    21.0
    7.7
    WATER BASED
    08.05.1989
    3361
    1.57
    22.0
    10.5
    WATER BASED
    08.05.1989
    3361
    1.56
    20.0
    7.7
    WATER BASED
    05.05.1989
    3361
    1.56
    22.0
    7.2
    WATER BASED
    05.05.1989
    3384
    1.57
    21.0
    8.1
    WATER BASED
    08.05.1989
    3460
    1.56
    19.0
    7.7
    WATER BASED
    10.05.1989
    3488
    1.57
    21.0
    7.7
    WATER BASED
    10.05.1989
    3517
    1.59
    17.0
    6.7
    WATER BASED
    19.05.1989
    3517
    1.38
    14.0
    4.3
    WATER BASED
    23.05.1989
    3517
    1.38
    13.0
    3.8
    WATER BASED
    24.05.1989
    3517
    1.38
    12.0
    3.8
    WATER BASED
    26.05.1989
    3517
    1.38
    12.0
    2.9
    WATER BASED
    29.05.1989
    3517
    1.38
    12.0
    2.9
    WATER BASED
    29.05.1989
    3517
    1.38
    12.0
    3.8
    WATER BASED
    29.05.1989
    3517
    1.38
    16.0
    3.8
    WATER BASED
    30.05.1989
    3517
    1.44
    14.0
    3.8
    WATER BASED
    31.05.1989
    3517
    1.44
    14.0
    3.8
    WATER BASED
    01.06.1989
    3517
    1.44
    WATER BASED
    05.06.1989
    3517
    1.59
    17.0
    5.7
    WATER BASED
    22.05.1989
    3517
    1.38
    13.0
    WATER BASED
    25.05.1989
    3529
    1.56
    18.0
    8.6
    WATER BASED
    11.05.1989
    3574
    1.59
    22.0
    8.1
    WATER BASED
    16.05.1989
    3574
    1.59
    21.0
    8.6
    WATER BASED
    16.05.1989
    3574
    1.59
    21.0
    8.1
    WATER BASED
    16.05.1989
    3574
    1.59
    21.0
    8.6
    WATER BASED
    18.05.1989
    3574
    1.59
    19.0
    8.1
    WATER BASED
    18.05.1989
    3574
    1.59
    17.0
    7.7
    WATER BASED
    18.05.1989
    3574
    1.57
    19.0
    8.1
    WATER BASED
    12.05.1989

  • 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
    0.21