Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
27.12.2024 - 01:25
Time of last synchronization with Norwegian Offshore Directorate's internal systems

30/6-18

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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.
    30/6-18
    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.
    30/6-18
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    NH 82 - 121 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.
    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.
    476-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.
    115
    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,
    01.08.1985
    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.
    23.11.1985
    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.
    23.11.1987
    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.
    28.05.2003
    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.
    EARLY 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.
    STATFJORD 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.
    108.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3690.0
    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).
    3686.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    4.8
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    148
    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.
    LATE TRIASSIC
    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.
    HEGRE GP
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    60° 30' 30.65'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 41' 20.65'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6708243.70
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    482923.04
    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.
    488

  • Wellbore history
    General
    Well 30/6-18 was drilled on the Kappa structure, which is located in the south-western corner of the block. Kappa is an elongated down faulted block bounded by north south trending major faults to the east and the west. The structure is an easterly tilted fault block where the Base Cretaceous truncates both the Brent Group and the Statfjord Formation. The main objective of the well was to prove hydrocarbons in the Statfjord Formation by drilling on a location that leaves a minimum of possible reserves up dip of the well. Secondary objectives were to improve stratigraphical and structural knowledge of the area and to acquire input data for further exploration activity in blocks 30/6 and 30/9.
    Operations and results
    Wildcat well 30/6-18 was spudded with the semi-submersible installation Byford Dolphin 1 August 1985 and drilled to TD at 3690 m in Late Triassic rocks. Drilling proceeded without any significant problems. The well was drilled with spud mud down to 658 m and with a KCl polymer mud from 658 m to TD. The Statfjord Formation came in 120 m higher than prognosed. The logs show that the Statfjord Formation contains 16 m of gas and 44 m of oil. Oi1/water contact was defined at 3181 m. The reservoir quality seems to be good. There is a separate column of 19 m oil further down in the Statfjord Formation. A thick shale sequence from 3287 to 3305 m separates the upper reservoir unit from the lower. The lower oil column is probably restricted to only one layer of sand with a gas cap on top. Eight cores were cut in the Statfjord Formation in the interval 3126 - 3215 m. Three sets of segregated RFT samples were retrieved from 3165 m, 3125.5 m, and 3312.8 m in the Statfjord Formation. The well was plugged and abandoned on 23 November 1985 as an oil and gas discovery.
    Testing
    Three drill stem tests were performed in this well. The intervals were 3306 m - 3323 m, 3198 m - 3210 m and 3164 m & 3173.2 m.

  • Cuttings at the Norwegian Offshore Directorate
    Cuttings at the Norwegian Offshore Directorate
    Cuttings available for sampling?
    NO
    Cuttings at the Norwegian Offshore Directorate
    Cutting sample, top depth [m]
    Cutting samples, bottom depth [m]
    230.00
    3690.00

  • 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
    3126.0
    3128.5
    [m ]
    2
    3139.0
    3146.2
    [m ]
    3
    3146.2
    3148.0
    [m ]
    4
    3148.0
    3166.6
    [m ]
    5
    3166.6
    3184.0
    [m ]
    6
    3184.0
    3187.6
    [m ]
    7
    3192.0
    3210.3
    [m ]
    8
    3210.3
    3215.0
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    74.0
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 3126-3129m
    Core photo at depth: 3139-3144m
    Core photo at depth: 3144-3146m
    Core photo at depth: 3146-3148m
    Core photo at depth: 3148-3153m
    3126-3129m
    3139-3144m
    3144-3146m
    3146-3148m
    3148-3153m
    Core photo at depth: 3153-3158m
    Core photo at depth: 3158-3163m
    Core photo at depth: 3163-3166m
    Core photo at depth: 3166-3171m
    Core photo at depth: 3171-3176m
    3153-3158m
    3158-3163m
    3163-3166m
    3166-3171m
    3171-3176m
    Core photo at depth: 3176-3181m
    Core photo at depth: 3181-3184m
    Core photo at depth: 3184-3188m
    Core photo at depth: 3192-3197m
    Core photo at depth: 3197-3202m
    3176-3181m
    3181-3184m
    3184-3188m
    3192-3197m
    3197-3202m
    Core photo at depth: 3202-3207m
    Core photo at depth: 3207-3210m
    Core photo at depth: 3210-3215m
    Core photo at depth: 3215-3217m
    Core photo at depth:  
    3202-3207m
    3207-3210m
    3210-3215m
    3215-3217m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    2626.0
    [m]
    SWC
    RRI
    2785.0
    [m]
    SWC
    RRI
    2880.0
    [m]
    DC
    RRI
    2890.0
    [m]
    DC
    RRI
    2900.0
    [m]
    SWC
    RRI
    2908.0
    [m]
    SWC
    RRI
    2912.0
    [m]
    SWC
    RRI
    2915.0
    [m]
    SWC
    RRI
    2918.0
    [m]
    SWC
    RRI
    2930.0
    [m]
    DC
    RRI
    2935.0
    [m]
    SWC
    RRI
    2952.5
    [m]
    SWC
    RRI
    2965.0
    [m]
    SWC
    RRI
    2970.0
    [m]
    DC
    RRI
    2975.0
    [m]
    SWC
    RRI
    2982.0
    [m]
    SWC
    RRI
    2990.0
    [m]
    SWC
    RRI
    2996.0
    [m]
    SWC
    RRI
    3000.0
    [m]
    DC
    RRI
    3001.5
    [m]
    SWC
    RRI
    3015.0
    [m]
    DC
    RRI
    3025.0
    [m]
    SWC
    RRI
    3058.0
    [m]
    SWC
    RRI
    3090.0
    [m]
    DC
    RRI
    3100.0
    [m]
    DC
    RRI
    3117.0
    [m]
    DC
    RRI
    3126.3
    [m]
    C
    RRI
    3128.5
    [m]
    C
    RRI
    3137.0
    [m]
    DC
    RRI
    3148.8
    [m]
    C
    RRI
    3159.2
    [m]
    C
    RRI
    3187.3
    [m]
    C
    RRI
    3193.1
    [m]
    C
    RRI
    3215.5
    [m]
    C
    RRI
    3238.0
    [m]
    SWC
    RRI
    3300.0
    [m]
    DC
    RRI
    3315.0
    [m]
    DC
    RRI
    3330.0
    [m]
    DC
    RRI
    3345.0
    [m]
    DC
    RRI
    3357.0
    [m]
    SWC
    RRI
    3360.0
    [m]
    DC
    RRI
    3375.0
    [m]
    DC
    RRI
    3383.2
    [m]
    SWC
    RRI
    3390.0
    [m]
    DC
    RRI
    3417.0
    [m]
    DC
    RRI
    3427.0
    [m]
    DC
    RRI
    3545.0
    [m]
    DC
    RRI
    3555.0
    [m]
    DC
    RRI

  • Oil samples at the Norwegian Offshore Directorate
    Oil samples at the Norwegian Offshore Directorate
    Test type
    Bottle number
    Top depth
    MD [m]
    Bottom depth
    MD [m]
    Fluid type
    Test time
    Samples available
    DST
    DST1A
    3307.00
    3324.00
    20.10.1985 - 00:00
    YES

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.64

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    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
    2.80
    pdf
    28.30

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    3307
    3324
    14.0
    2.0
    3198
    3210
    14.0
    3.0
    3164
    3173
    14.0
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    126
    2.0
    122
    3.0
    119
    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
    609
    161970
    0.811
    265
    2.0
    871
    2832
    3.0
    957
    189744
    0.845
    0.705
    198

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL VDL
    430
    1598
    CET CBL VDL
    1152
    3400
    CST
    1997
    3116
    CST
    1997
    3122
    CST
    3035
    3383
    CST
    3435
    3690
    DLL MSFL GR
    3085
    3210
    DLL MSFL GR
    3181
    3415
    HRT
    50
    1700
    ISF LSS SP GR
    321
    652
    ISF LSS SP GR
    644
    1599
    ISF LSS SP GR
    1598
    3211
    ISF LSS SP GR
    3186
    3424
    ISF LSS SP GR
    3419
    3692
    LDT CAL GR
    644
    1598
    LDT CNL CAL GR
    1598
    3213
    LDT CNL NGT CAL GR
    3050
    3423
    LDT CNL NGT CAL GR
    3419
    3693
    MWD - RES GR
    1650
    3185
    RFT
    3122
    3195
    RFT
    3122
    3402
    RFT
    3125
    3126
    RFT
    3429
    3683
    SHDT
    1598
    3418
    SHDT
    3419
    3692
    VSP
    898
    3379

  • 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
    219.0
    36
    219.0
    0.00
    LOT
    SURF.COND.
    20
    643.5
    26
    654.0
    1.43
    LOT
    INTERM.
    13 3/8
    1598.0
    17 1/2
    1613.0
    1.79
    LOT
    INTERM.
    9 5/8
    3413.0
    12 1/4
    3486.0
    1.76
    LOT
    OPEN HOLE
    3690.0
    8 3/8
    3690.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    150
    1.03
    WATER BASED
    25.11.1985
    214
    1.05
    WATER BASED
    02.08.1985
    214
    1.05
    WATER BASED
    06.08.1985
    214
    1.05
    WATER BASED
    06.08.1985
    525
    1.07
    5.0
    35.0
    WATER BASED
    06.08.1985
    654
    1.16
    5.0
    21.0
    WATER BASED
    06.08.1985
    654
    1.16
    5.0
    22.0
    WATER BASED
    06.08.1985
    654
    1.16
    5.0
    23.0
    WATER BASED
    08.08.1985
    654
    1.15
    16.0
    11.0
    WATER BASED
    13.08.1985
    654
    1.16
    5.0
    22.0
    WATER BASED
    06.08.1985
    654
    1.15
    16.0
    10.0
    WATER BASED
    09.08.1985
    654
    1.15
    16.0
    11.0
    WATER BASED
    13.08.1985
    654
    1.15
    16.0
    10.0
    WATER BASED
    09.08.1985
    654
    1.16
    5.0
    23.0
    WATER BASED
    08.08.1985
    881
    1.20
    15.0
    11.0
    WATER BASED
    13.08.1985
    1282
    1.21
    22.0
    12.0
    WATER BASED
    14.08.1985
    1494
    1.28
    27.0
    14.0
    WATER BASED
    19.08.1985
    1613
    1.30
    30.0
    16.0
    WATER BASED
    21.08.1985
    1613
    1.30
    26.0
    13.0
    WATER BASED
    21.08.1985
    1613
    1.30
    27.0
    12.0
    WATER BASED
    21.08.1985
    1613
    1.26
    26.0
    12.0
    WATER BASED
    21.08.1985
    1650
    1.35
    37.0
    13.0
    WATER BASED
    22.08.1985
    1982
    1.35
    37.0
    16.0
    WATER BASED
    23.08.1985
    2172
    1.38
    23.0
    11.0
    WATER BASED
    27.08.1985
    2386
    1.38
    27.0
    11.0
    WATER BASED
    27.08.1985
    2464
    1.39
    30.0
    12.0
    WATER BASED
    27.08.1985
    2607
    1.39
    10.0
    18.0
    WATER BASED
    29.08.1985
    2727
    1.39
    23.0
    8.0
    WATER BASED
    29.08.1985
    2771
    1.39
    20.0
    7.0
    WATER BASED
    30.08.1985
    2867
    1.39
    20.0
    8.0
    WATER BASED
    03.09.1985
    2918
    1.39
    19.0
    7.0
    WATER BASED
    03.09.1985
    3021
    1.41
    18.0
    6.0
    WATER BASED
    03.09.1985
    3070
    1.42
    21.0
    7.0
    WATER BASED
    03.09.1985
    3126
    1.42
    19.0
    8.0
    WATER BASED
    05.09.1985
    3134
    1.34
    WATER BASED
    22.11.1985
    3136
    1.42
    21.0
    8.0
    WATER BASED
    06.09.1985
    3146
    1.42
    27.0
    9.0
    WATER BASED
    06.09.1985
    3164
    1.34
    WATER BASED
    20.11.1985
    3164
    1.34
    WATER BASED
    21.11.1985
    3166
    1.41
    24.0
    9.0
    WATER BASED
    09.09.1985
    3182
    1.34
    WATER BASED
    04.11.1985
    3182
    1.34
    WATER BASED
    05.11.1985
    3182
    1.34
    WATER BASED
    06.11.1985
    3182
    1.34
    WATER BASED
    12.11.1985
    3182
    1.34
    WATER BASED
    10.11.1985
    3182
    1.34
    WATER BASED
    20.11.1985
    3182
    1.34
    WATER BASED
    07.11.1985
    3184
    1.41
    24.0
    8.0
    WATER BASED
    09.09.1985
    3192
    1.39
    27.0
    9.0
    WATER BASED
    09.09.1985
    3195
    1.35
    21.0
    8.0
    WATER BASED
    16.09.1985
    3197
    1.34
    WATER BASED
    04.11.1985
    3215
    1.35
    22.0
    7.0
    WATER BASED
    16.09.1985
    3215
    1.39
    23.0
    8.0
    WATER BASED
    12.09.1985
    3215
    1.35
    21.0
    7.0
    WATER BASED
    16.09.1985
    3215
    1.39
    23.0
    8.0
    WATER BASED
    11.09.1985
    3215
    1.39
    22.0
    8.0
    WATER BASED
    12.09.1985
    3215
    1.33
    21.0
    8.0
    WATER BASED
    13.09.1985
    3285
    1.35
    24.0
    10.0
    WATER BASED
    24.09.1985
    3304
    1.34
    WATER BASED
    23.10.1985
    3304
    1.34
    WATER BASED
    29.10.1985
    3304
    1.34
    WATER BASED
    30.10.1985
    3304
    1.34
    WATER BASED
    31.10.1985
    3322
    1.35
    26.0
    9.0
    WATER BASED
    24.09.1985
    3371
    1.35
    27.0
    10.0
    WATER BASED
    24.09.1985
    3372
    1.33
    21.0
    6.0
    WATER BASED
    09.10.1985
    3372
    1.33
    21.0
    6.0
    WATER BASED
    09.10.1985
    3372
    1.33
    24.0
    10.0
    WATER BASED
    10.10.1985
    3372
    1.36
    WATER BASED
    16.10.1985
    3372
    1.35
    WATER BASED
    17.10.1985
    3372
    1.35
    WATER BASED
    18.10.1985
    3372
    1.34
    WATER BASED
    21.10.1985
    3372
    1.34
    WATER BASED
    22.10.1985
    3372
    1.34
    WATER BASED
    20.10.1985
    3372
    1.34
    WATER BASED
    24.10.1985
    3372
    1.34
    WATER BASED
    23.10.1985
    3390
    1.33
    21.0
    6.0
    WATER BASED
    07.10.1985
    3428
    1.35
    28.0
    12.0
    WATER BASED
    24.09.1985
    3428
    1.35
    29.0
    11.0
    WATER BASED
    24.09.1985
    3428
    1.35
    29.0
    12.0
    WATER BASED
    24.09.1985
    3428
    1.35
    27.0
    9.0
    WATER BASED
    25.09.1985
    3428
    1.35
    27.0
    9.0
    WATER BASED
    03.10.1985
    3428
    1.35
    27.0
    9.0
    WATER BASED
    27.09.1985
    3451
    1.31
    23.0
    5.0
    WATER BASED
    03.10.1985
    3527
    1.31
    25.0
    6.0
    WATER BASED
    03.10.1985
    3588
    1.31
    25.0
    8.0
    WATER BASED
    03.10.1985
    3650
    1.31
    25.0
    8.0
    WATER BASED
    03.10.1985
    3690
    1.33
    26.0
    7.0
    WATER BASED
    07.10.1985

  • 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