Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
12.05.2024 - 01:31
Time of last synchronization with Norwegian Offshore Directorate's internal systems

30/6-16

Export: PDF icon PDF

  • General information
    General information
    Attribute Value
    Wellbore name
    Official name of wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    30/6-16
    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
    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.
    30/6-16
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    NH 82 - 344 SP. 300.
    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.
    442-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.
    74
    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,
    09.11.1984
    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.
    21.01.1985
    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.
    21.01.1987
    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.
    29.03.2014
    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.
    ETIVE FM
    2nd level with HC, age
    Age of lithostratigraphic unit, 2nd level, where hydrocarbons were encountered. Examples of legal values: CRETACEOUS, EARLY CRETACEOUS, LATE JURASSIC, EOCENE.
    EARLY JURASSIC
    2nd level with HC, formation
    Name of lithostartigraphic unit, 2nd level, where hydrocarbons were encountered. Shown only for released wells. Examples of legal values: BASEMENT, COOK FM, EKOFISK FM, HEIMDAL FM, SANDNES FM, SOGNEFJORD FM, TARBERT FM, BRENT GP.
    COOK FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    23.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    114.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3300.0
    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).
    3300.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    1.8
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    126
    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.
    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° 39' 31.72'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 41' 37.64'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6724982.82
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    483260.18
    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.
    333

  • Wellbore history
    General
    Wildcat well 30/6-16 was drilled on the Theta structure, immediately northwest of the main Oseberg Alpha North structure. The main objective of the well was to prove hydrocarbons in the Statfjord Formation. Planned TD was ca 3150 m or ca 225 m into the Statfjord Formation.
    Operations and results
    Wildcat well 30/6-16 was spudded with the semi-submersible installation Treasure scout on 9 November 1984 and drilled to TD at 3300 m in the Triassic Hegre Group. Drilling proceeded without significant problems. The well was drilled with spud mud down to 613 m and with KCl/polymer mud from 613 m to TD.
    Good oil shows were reported on dolomite and limestone beds and stringers from 1993 to 2333 m in the Rogaland and Shetland groups. From 2605 to 2853 (Shetland Group) good oil shows were recorded in sandstones and siltstones as well as in limestones. The Brent Group was encountered at 2856 m and consisted of 12 m Etive Formation only. The Etive Formation was found to be oil bearing over the entire interval. The net pay was 6.3 m with average log porosity of 19.1%. Also the 26 m thick Cook Formation with top at 2920 m was oil bearing all through. Net pay here was 12.6 m with average log porosity of 19.0%. No oil/water contacts could be established. The Statfjord Formation had weak shows in the top 10 m, but was found to be water bearing. RFT pressure recordings and sampling were recorded in 5 runs.  Different pressure regimes were proved for the Etive Formation, the Cook Formation and the Statfjord Group.
    Four cores were cut in the Etive and Drake Formations (2856 - 2909 m), two in the Cook and Amundsen/Burton formations (2923 - 2949 m) and one in the Statfjord Formation (2982 - 2990 m). RFT fluid samples were taken at 2857 m (oil, gas and water), 2929.5 m (water, gas and some oil) and 3194.5 m (water).
    The well was permanently abandoned on 21 January 1985 as an oil discovery.
    Testing
    Two Drill Stem Tests were performed. Overall test data indicated severe depletion effects in both reservoirs.
    DST 1 tested the interval: 2919.6 - 2943.6 m in the Cook Formation. The average production was 183 Sm3 oil and 25500 Sm3 gas /day through a 36/64" choke.  GOR was 139 Sm3/Sm3. Oil gravity was 29 deg API and gas gravity was 0.747 (rel. to air) with 2.4 % CO2 and no H2S. The bottom hole temperature in the test was 113.3 deg C.
    DST 2 tested the interval: 2855-2868 m in the Etive Formation. The average production was 685 Sm3 oil and 125000 Sm3 gas /day through a 68/64" choke. GOR was 182 Sm3/Sm3.  Oil gravity was 36 deg API and gas gravity was 0.76 (rel. to air) with 2.3% CO2 and no H2S. The bottom hole temperature in the test was 113.4 deg C.
    A rapid decrease in production rate and well head pressure in the Etive Formation test indicate that the reservoir is of very limited size.

  • 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
    3300.00

  • 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
    2856.0
    2866.0
    [m ]
    2
    2866.0
    2877.2
    [m ]
    3
    2878.5
    2889.9
    [m ]
    4
    2890.0
    2906.0
    [m ]
    5
    2923.0
    2937.4
    [m ]
    6
    2937.4
    2948.4
    [m ]
    7
    2982.0
    2989.9
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    81.8
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 2856-2861m
    Core photo at depth: 2861-2768m
    Core photo at depth: 2866-2871m
    Core photo at depth: 2871-2876m
    Core photo at depth: 2876-2877m
    2856-2861m
    2861-2768m
    2866-2871m
    2871-2876m
    2876-2877m
    Core photo at depth: 2878-2883m
    Core photo at depth: 2883-2888m
    Core photo at depth: 2888-2889m
    Core photo at depth: 2890-2895m
    Core photo at depth: 2895-2900m
    2878-2883m
    2883-2888m
    2888-2889m
    2890-2895m
    2895-2900m
    Core photo at depth: 2900-2905m
    Core photo at depth: 2905-2906m
    Core photo at depth: 2923-2928m
    Core photo at depth: 2928-2933m
    Core photo at depth: 2933-2937m
    2900-2905m
    2905-2906m
    2923-2928m
    2928-2933m
    2933-2937m
    Core photo at depth: 2937-2942m
    Core photo at depth: 2942-2947m
    Core photo at depth: 2947-2948m
    Core photo at depth: 2982-2987m
    Core photo at depth: 2987-2989m
    2937-2942m
    2942-2947m
    2947-2948m
    2982-2987m
    2987-2989m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    2817.0
    [m]
    SWC
    RRI
    2837.0
    [m]
    SWC
    RRI
    2847.0
    [m]
    SWC
    RRI
    2850.0
    [m]
    SWC
    RRI
    2852.0
    [m]
    SWC
    RRI
    2884.1
    [m]
    C
    OD
    2898.1
    [m]
    C
    OD
    2914.0
    [m]
    SWC
    RRI
    2926.8
    [m]
    C
    OD
    2956.5
    [m]
    SWC
    RRI
    2960.0
    [m]
    SWC
    RRI
    2975.5
    [m]
    SWC
    RRI
    3013.0
    [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
    2944.00
    2920.00
    14.01.1985 - 00:00
    YES
    DST
    DST2
    2855.00
    2868.00
    18.01.1985 - 00:00
    YES

  • Lithostratigraphy

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.27
    pdf
    0.87

  • 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
    11.47

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    2920
    2944
    15.9
    1.1
    2920
    2944
    14.3
    2.0
    2855
    2868
    27.0
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    3.000
    1.1
    3.000
    2.0
    10.000
    28.000
    Drill stem tests (DST)
    Test number
    Oil
    [Sm3/day]
    Gas
    [Sm3/day]
    Oil density
    [g/cm3]
    Gas grav. rel.air
    GOR
    [m3/m3]
    1.0
    165
    2475
    0.880
    0.747
    15
    1.1
    175
    26000
    0.880
    0.747
    150
    2.0
    710
    142000
    0.840
    0.760
    200

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL VDL GR
    400
    3221
    CBL VDL GR CCL
    2335
    2906
    CET CAL
    1500
    3221
    CST GR
    2002
    2851
    CST GR
    2852
    3293
    CST GR CCL
    1500
    3221
    DLL MSFL GR
    2820
    3230
    ISF LSS GR
    224
    3302
    ISF MSFL LSS GR
    2840
    2984
    LDL CNL GR
    597
    2985
    LDL CNL NGT
    2820
    3304
    RFT
    2855
    2861
    RFT
    2855
    3246
    RFT
    2926
    2932
    RFT
    2926
    2930
    RFT
    3194
    3194
    SAT VSP
    683
    3303
    SAT VSP
    2351
    2411
    SHDT
    2000
    3304
    WGR
    320
    597

  • 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
    223.5
    36
    224.0
    0.00
    LOT
    SURF.COND.
    20
    598.5
    26
    613.0
    1.43
    LOT
    INTERM.
    13 3/8
    1703.0
    17 1/2
    1715.0
    1.65
    LOT
    INTERM.
    9 5/8
    3285.0
    12 1/4
    3300.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    224
    1.05
    WATER BASED
    12.11.1984
    224
    1.08
    WATER BASED
    13.11.1984
    224
    1.08
    WATER BASED
    13.11.1984
    302
    1.08
    WATER BASED
    14.11.1984
    613
    1.08
    12.0
    30.0
    WATER BASED
    15.11.1984
    613
    1.14
    14.0
    32.0
    WATER BASED
    16.11.1984
    613
    1.14
    14.0
    32.0
    WATER BASED
    16.11.1984
    627
    1.14
    19.0
    13.0
    WATER BASED
    21.11.1984
    1231
    1.16
    18.0
    12.0
    WATER BASED
    22.11.1984
    1241
    1.16
    18.0
    13.0
    WATER BASED
    23.11.1984
    1415
    1.17
    20.0
    12.0
    WATER BASED
    26.11.1984
    1715
    1.17
    19.0
    12.0
    WATER BASED
    26.11.1984
    1715
    1.19
    20.0
    13.0
    WATER BASED
    26.11.1984
    1715
    1.18
    22.0
    12.0
    WATER BASED
    27.11.1984
    1715
    1.19
    20.0
    13.0
    WATER BASED
    26.11.1984
    1715
    1.18
    22.0
    12.0
    WATER BASED
    27.11.1984
    1715
    1.20
    20.0
    10.0
    WATER BASED
    28.11.1984
    1715
    1.20
    20.0
    10.0
    WATER BASED
    28.11.1984
    1773
    1.30
    24.0
    13.0
    WATER BASED
    29.11.1984
    2000
    1.40
    32.0
    14.0
    WATER BASED
    30.11.1984
    2160
    1.40
    27.0
    10.0
    WATER BASED
    04.12.1984
    2168
    1.40
    33.0
    11.0
    WATER BASED
    04.12.1984
    2350
    1.40
    30.0
    10.0
    WATER BASED
    04.12.1984
    2462
    1.40
    32.0
    13.0
    WATER BASED
    04.12.1984
    2566
    1.40
    29.0
    10.0
    WATER BASED
    05.12.1984
    2672
    1.40
    28.0
    10.0
    WATER BASED
    06.12.1984
    2728
    1.40
    28.0
    10.0
    WATER BASED
    07.12.1984
    2804
    1.40
    30.0
    11.0
    WATER BASED
    11.12.1984
    2856
    1.40
    28.0
    WATER BASED
    11.12.1984
    2859
    1.40
    25.0
    11.0
    WATER BASED
    11.12.1984
    2860
    1.35
    28.0
    11.0
    WATER BASED
    12.12.1984
    2860
    0.00
    28.0
    12.0
    WATER BASED
    15.12.1984
    2860
    0.00
    30.0
    13.0
    WATER BASED
    15.12.1984
    2860
    0.00
    31.0
    12.0
    WATER BASED
    15.12.1984
    2860
    0.00
    29.0
    12.0
    WATER BASED
    15.12.1984
    2860
    1.35
    29.0
    12.0
    WATER BASED
    20.12.1984
    2860
    1.36
    30.0
    12.0
    WATER BASED
    20.12.1984
    2860
    1.35
    23.0
    10.0
    WATER BASED
    11.12.1984
    2860
    1.35
    28.0
    14.0
    WATER BASED
    11.12.1984
    2860
    1.35
    30.0
    13.0
    WATER BASED
    16.12.1984
    2860
    1.36
    30.0
    12.0
    WATER BASED
    20.12.1984
    2860
    1.35
    28.0
    14.0
    WATER BASED
    11.12.1984
    2860
    1.35
    28.0
    11.0
    WATER BASED
    12.12.1984
    2860
    1.35
    28.0
    12.0
    WATER BASED
    16.12.1984
    2860
    1.36
    31.0
    12.0
    WATER BASED
    16.12.1984
    2860
    1.35
    29.0
    12.0
    WATER BASED
    16.12.1984
    2860
    1.35
    29.0
    12.0
    WATER BASED
    20.12.1984
    2884
    1.32
    WATER BASED
    14.01.1985
    2884
    1.32
    WATER BASED
    18.01.1985
    2884
    1.32
    WATER BASED
    07.01.1985
    2884
    1.32
    WATER BASED
    15.01.1985
    2884
    1.32
    WATER BASED
    17.01.1985
    2884
    1.32
    WATER BASED
    21.01.1985
    2884
    1.32
    WATER BASED
    06.01.1985
    2884
    1.32
    WATER BASED
    07.01.1985
    2884
    1.32
    WATER BASED
    14.01.1985
    2884
    1.32
    WATER BASED
    15.01.1985
    2884
    1.32
    WATER BASED
    17.01.1985
    2884
    1.32
    WATER BASED
    18.01.1985
    2884
    1.32
    WATER BASED
    21.01.1985
    2926
    1.35
    28.0
    11.0
    WATER BASED
    13.12.1984
    3160
    1.36
    29.0
    12.0
    WATER BASED
    19.12.1984
    3160
    1.36
    29.0
    12.0
    WATER BASED
    18.12.1984
    3224
    1.32
    WATER BASED
    01.01.1985
    3224
    1.32
    WATER BASED
    01.01.1985
    3224
    1.32
    WATER BASED
    02.01.1985
    3224
    1.32
    WATER BASED
    03.01.1985
    3224
    1.32
    WATER BASED
    06.01.1985
    3224
    1.32
    WATER BASED
    03.01.1985
    3224
    1.36
    54.0
    WATER BASED
    01.01.1985
    3224
    1.32
    WATER BASED
    01.01.1985
    3224
    1.32
    WATER BASED
    01.01.1985
    3224
    1.32
    WATER BASED
    02.01.1985
    3224
    1.32
    WATER BASED
    06.01.1985
    3300
    1.35
    29.0
    12.0
    WATER BASED
    26.12.1984
    3300
    1.35
    WATER BASED
    26.12.1984
    3300
    1.35
    30.0
    12.0
    WATER BASED
    26.12.1984
    3300
    1.35
    30.0
    11.0
    WATER BASED
    26.12.1984
    3300
    1.36
    WATER BASED
    27.12.1984
    3300
    1.36
    29.0
    12.0
    WATER BASED
    26.12.1984
    3300
    1.36
    29.0
    12.0
    WATER BASED
    26.12.1984
    3300
    1.35
    WATER BASED
    26.12.1984
    3300
    1.35
    30.0
    12.0
    WATER BASED
    26.12.1984
    3300
    1.35
    30.0
    11.0
    WATER BASED
    26.12.1984
    3300
    1.36
    WATER BASED
    27.12.1984

  • 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