Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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sodir.no          Norsk
27.12.2024 - 01:25
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30/9-11 A

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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.
    30/9-11 A
    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
    Well name
    Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    30/9-11
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    NH 8502-187 CDP-LINJE 1508 - COL 745
    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.
    658-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.
    40
    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,
    20.11.1990
    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.
    29.12.1990
    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.
    29.12.1992
    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.
    06.01.2014
    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.
    APPRAISAL
    Reentry
    Status whether the wellbore has been re-entered (YES) or not (NO). Re-entered wellbores are not included in the count when wellbores are presented in statistical overviews.
    NO
    Content
    For exploration wellbores, status of discovery.

    Legal values:
    DRY, SHOWS (trace amounts of hydrocarbons), GAS, GAS/CONDENSATE, OIL or OIL/GAS.
    SHOWS (GAS SHOWS, OIL SHOWS or OIL/GAS SHOWS) are detected as fluorescent cut (organic extract), petroleum odour, or visual stain on cuttings or cores, or as increased gas reading on the mud-loggers gas detection equipment.
    Legal values for WILDCAT-CCS and APPRAISAL-CCS: WATER

    For development wellbores, type of produced/injected fluid.
    Legal values:
    WATER, CUTTINGS, NOT AVAILABLE, OIL, GAS/CONDENSATE, OIL/GAS, CO2, GAS, WATER/GAS, NOT APPLICABLE.
    SHOWS
    Discovery wellbore
    Indicator which tells if the wellbore made a new discovery. Legal values: YES, NO. Prior to press-release or other information regarding drilling results, the indicator will be “NO” as a default.
    NO
    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).
    3002.0
    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).
    2734.0
    Oldest penetrated age
    Age (according to Geologic Time Scale 2004 by F. M. Gradstein, et al. (2004)) of the oldest penetrated formation. May differ from age at TD for example in deviated wellbores. Examples of legal values: CRETACEOUS, EARLY CRETACEOUS, LATE JURASSIC, EARLY PERMIAN, EARLY TRIASSIC, EOCENE.
    EARLY JURASSIC
    Oldest penetrated formation
    Name of the oldest lithostratigraphic unit penetrated by the wellbore. Shown only for released wells. In most wellbores this is formation or group at total depth. May differ from formation or group at TD for example in wellbores drilled with high deviation or through faults. Examples of legal values: AMUNDSEN FM, BALDER FM, BASEMENT, BLODØKS FM, BRYNE FM, BURTON FM, COOK FM, DRAKE FM, DRAUPNE FM, EKOFISK FM, DUNLIN GP.
    STATFJORD GP
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    60° 19' 27.89'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 55' 44'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6687700.50
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    496072.29
    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.
    1705

  • Wellbore history
    General
    Well 30/9-11 A was drilled as a sidetrack to well 30/9-11 on the J-structure on the Oseberg Sør field in the North Sea.
    The vertical 30/9-11 well drilled a dry Brent group in J-East segment. The sidetrack targeted the J-Central segment and should penetrate top of the Brent Group in a down flank position in order to confirm deep oil filling of the J-Central segment, where oil previously had been discovered by well 30/9-9. The primary target was the Brent Group. Secondary target was the Cook Formation.
    Operations and results
    Well 30/9-11 A was kicked off from 920 m in 30/9-11 on 20 November 1990. The well was drilled with the semi-submersible installation Vildkat to TD at 3002 m (2735 m TVD) in Early Jurassic sediments of the Statfjord Group. Apart from some tight hole problems and close to seven days wait on weather operations proceeded without significant problems. The well was drilled with KCl/polymer mud from kick-off to TD.
    Top Viking Group, Heather Formation was encountered at 2513 m and top Brent Group, Ness Formation was encountered at 2553 m. The Ness Formation was water bearing, however moderate oil shows with strong petroleum odour was described on cores from top off the Ness Formation down to 2570 m. These shows were confirmed by relatively high organic geochemical extract yields with oil-mature biomarkers. Poor shows were described also in Shetland Group limestone from 2455 to 2457 m and in Heather Formation claystone from 2517 to 2520 m. Otherwise there were no indications of hydrocarbons in the well.
    Three cores were cut in from 2545 to 2582 m in the Heather, Tarbert, and Ness Formation. A fourth core was cut from 2652 to 2660 m in the lower Ness Formation. Good recovery was obtained in all cores. RFT water samples were taken at 2551.6 m and 2558 m.
    The well was permanently abandoned on 29 December 1990 as a dry well with shows.
    Testing
    No drill stem test was performed.

  • 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]
    930.00
    3002.00

  • 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
    2545.0
    2552.2
    [m ]
    2
    2553.0
    2575.0
    [m ]
    3
    2576.0
    2578.0
    [m ]
    4
    2652.0
    2660.0
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    39.1
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 2545-2550m
    Core photo at depth: 2550-2555m
    Core photo at depth: 2555-2560m
    Core photo at depth: 2560-2565m
    Core photo at depth: 2565-2570m
    2545-2550m
    2550-2555m
    2555-2560m
    2560-2565m
    2565-2570m
    Core photo at depth: 2570-2574m
    Core photo at depth: 2576-2581m
    Core photo at depth: 2581-2581m
    Core photo at depth: 2652-2657m
    Core photo at depth: 2657-2659m
    2570-2574m
    2576-2581m
    2581-2581m
    2652-2657m
    2657-2659m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    940.0
    [m]
    DC
    STRAT
    960.0
    [m]
    DC
    STRAT
    970.0
    [m]
    DC
    STRAT
    990.0
    [m]
    DC
    STRAT
    1000.0
    [m]
    DC
    STRAT
    1020.0
    [m]
    DC
    STRAT
    1030.0
    [m]
    DC
    STRAT
    1050.0
    [m]
    DC
    STRAT
    1060.0
    [m]
    DC
    STRAT
    1080.0
    [m]
    DC
    STRAT
    1090.0
    [m]
    DC
    STRAT
    1110.0
    [m]
    DC
    STRAT
    1120.0
    [m]
    DC
    STRAT
    1140.0
    [m]
    DC
    STRAT
    1150.0
    [m]
    DC
    STRAT
    1170.0
    [m]
    DC
    STRAT
    1180.0
    [m]
    DC
    STRAT
    1200.0
    [m]
    DC
    STRAT
    1210.0
    [m]
    DC
    STRAT
    1230.0
    [m]
    DC
    STRAT
    1240.0
    [m]
    DC
    STRAT
    1260.0
    [m]
    DC
    STRAT
    1270.0
    [m]
    DC
    STRAT
    1290.0
    [m]
    DC
    STRAT
    1300.0
    [m]
    DC
    STRAT
    1320.0
    [m]
    DC
    STRAT
    1330.0
    [m]
    DC
    STRAT
    1350.0
    [m]
    DC
    STRAT
    1360.0
    [m]
    DC
    STRAT
    1380.0
    [m]
    DC
    STRAT
    1390.0
    [m]
    DC
    STRAT
    1410.0
    [m]
    DC
    STRAT
    1420.0
    [m]
    DC
    STRAT
    1440.0
    [m]
    DC
    STRAT
    1450.0
    [m]
    DC
    STRAT
    1470.0
    [m]
    DC
    STRAT
    1480.0
    [m]
    DC
    STRAT
    1500.0
    [m]
    DC
    STRAT
    1520.0
    [m]
    DC
    STRAT
    1530.0
    [m]
    DC
    STRAT
    1550.0
    [m]
    DC
    STRAT
    1560.0
    [m]
    DC
    STRAT
    1580.0
    [m]
    DC
    STRAT
    1590.0
    [m]
    DC
    STRAT
    1610.0
    [m]
    DC
    STRAT
    1620.0
    [m]
    DC
    STRAT
    1640.0
    [m]
    DC
    STRAT
    1650.0
    [m]
    DC
    STRAT
    1670.0
    [m]
    DC
    STRAT
    1690.0
    [m]
    DC
    STRAT
    1700.0
    [m]
    DC
    STRAT
    1720.0
    [m]
    DC
    STRAT
    1730.0
    [m]
    DC
    STRAT
    1750.0
    [m]
    DC
    STRAT
    1760.0
    [m]
    DC
    STRAT
    1780.0
    [m]
    DC
    STRAT
    1790.0
    [m]
    DC
    STRAT
    1810.0
    [m]
    DC
    STRAT
    1820.0
    [m]
    DC
    STRAT
    1840.0
    [m]
    DC
    STRAT
    1850.0
    [m]
    DC
    STRAT
    1870.0
    [m]
    DC
    STRAT
    1880.0
    [m]
    DC
    STRAT
    1900.0
    [m]
    DC
    STRAT
    1910.0
    [m]
    DC
    STRAT
    1930.0
    [m]
    DC
    STRAT
    1960.0
    [m]
    DC
    STRAT
    1970.0
    [m]
    DC
    STRAT
    1990.0
    [m]
    DC
    STRAT
    2000.0
    [m]
    DC
    STRAT
    2020.0
    [m]
    DC
    STRAT
    2030.0
    [m]
    DC
    STRAT
    2050.0
    [m]
    DC
    STRAT
    2060.0
    [m]
    DC
    STRAT
    2080.0
    [m]
    DC
    STRAT
    2090.0
    [m]
    DC
    STRAT
    2110.0
    [m]
    DC
    STRAT
    2120.0
    [m]
    DC
    STRAT
    2140.0
    [m]
    DC
    STRAT
    2150.0
    [m]
    DC
    STRAT
    2170.0
    [m]
    DC
    STRAT
    2180.0
    [m]
    DC
    STRAT
    2200.0
    [m]
    DC
    STRAT
    2210.0
    [m]
    DC
    STRAT
    2230.0
    [m]
    DC
    STRAT
    2240.0
    [m]
    DC
    STRAT
    2260.0
    [m]
    DC
    STRAT
    2270.0
    [m]
    DC
    STRAT
    2290.0
    [m]
    DC
    STRAT
    2300.0
    [m]
    DC
    STRAT
    2310.0
    [m]
    DC
    STRAT
    2325.0
    [m]
    DC
    STRAT
    2345.0
    [m]
    DC
    STRAT
    2370.0
    [m]
    DC
    STRAT
    2400.0
    [m]
    DC
    STRAT
    2409.0
    [m]
    DC
    HYDRO
    2417.0
    [m]
    DC
    STRAT
    2425.0
    [m]
    DC
    STRAT
    2431.5
    [m]
    SWC
    HYDRO
    2447.0
    [m]
    SWC
    HYDRO
    2460.0
    [m]
    DC
    STRAT
    2475.0
    [m]
    DC
    STRAT
    2485.0
    [m]
    DC
    STRAT
    2495.0
    [m]
    DC
    STRAT
    2505.0
    [m]
    DC
    STRAT
    2515.0
    [m]
    SWC
    HYDRO
    2521.0
    [m]
    SWC
    HYDRO
    2527.0
    [m]
    SWC
    HYDRO
    2536.0
    [m]
    SWC
    HYDRO
    2540.5
    [m]
    SWC
    HYDRO
    2542.0
    [m]
    SWC
    HYDRO
    2545.3
    [m]
    C
    HYDRO
    2545.9
    [m]
    C
    HYDRO
    2546.5
    [m]
    C
    HYDRO
    2546.7
    [m]
    C
    HYDRO
    2548.0
    [m]
    SWC
    HYDRO
    2548.3
    [m]
    C
    HYDRO
    2552.1
    [m]
    C
    HYDRO
    2553.5
    [m]
    C
    HYDRO
    2556.7
    [m]
    C
    HYDRO
    2559.9
    [m]
    C
    HYDRO
    2570.1
    [m]
    C
    HYDRO
    2570.8
    [m]
    C
    HYDRO
    2572.8
    [m]
    C
    HYDRO
    2581.4
    [m]
    C
    HYDRO
    2588.0
    [m]
    SWC
    HYDRO
    2591.0
    [m]
    SWC
    HYDRO
    2597.5
    [m]
    SWC
    HYDRO
    2608.0
    [m]
    SWC
    HYDRO
    2622.0
    [m]
    DC
    HYDRO
    2633.5
    [m]
    SWC
    HYDRO
    2644.0
    [m]
    SWC
    HYDRO
    2650.0
    [m]
    SWC
    HYDRO
    2652.0
    [m]
    C
    HYDRO
    2655.7
    [m]
    C
    HYDRO
    2657.7
    [m]
    C
    HYDRO
    2659.9
    [m]
    C
    HYDRO
    2670.0
    [m]
    SWC
    HYDRO
    2677.0
    [m]
    SWC
    HYDRO
    2680.0
    [m]
    DC
    STRAT
    2686.5
    [m]
    SWC
    HYDRO
    2696.0
    [m]
    DC
    STRAT
    2702.0
    [m]
    SWC
    HYDRO
    2715.0
    [m]
    DC
    STRAT
    2727.0
    [m]
    SWC
    HYDRO
    2747.0
    [m]
    DC
    STRAT
    2758.5
    [m]
    SWC
    HYDRO
    2770.0
    [m]
    DC
    STRAT
    2783.5
    [m]
    SWC
    HYDRO
    2794.0
    [m]
    SWC
    HYDRO
    2805.0
    [m]
    DC
    STRAT
    2815.0
    [m]
    DC
    STRAT
    2823.5
    [m]
    SWC
    HYDRO
    2832.0
    [m]
    DC
    STRAT
    2840.0
    [m]
    DC
    STRAT
    2850.0
    [m]
    DC
    STRAT
    2860.0
    [m]
    DC
    STRAT
    2870.0
    [m]
    DC
    STRAT
    2880.0
    [m]
    DC
    STRAT
    2890.0
    [m]
    DC
    STRAT
    2900.0
    [m]
    DC
    STRAT
    2910.0
    [m]
    DC
    STRAT
    2920.0
    [m]
    DC
    STRAT
    2930.0
    [m]
    DC
    STRAT
    2940.0
    [m]
    DC
    STRAT
    2950.0
    [m]
    DC
    STRAT
    2960.0
    [m]
    DC
    STRAT
    2970.0
    [m]
    DC
    STRAT
    2980.0
    [m]
    DC
    STRAT
    2990.0
    [m]
    DC
    STRAT
    3002.0
    [m]
    DC
    HYDRO

  • Lithostratigraphy

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.37
    pdf
    8.02

  • 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
    1.97
    pdf
    33.35

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CST GR
    2431
    2823
    DIL LSS GR SP AMS
    906
    2873
    DLL GR SP CAL AMS
    2525
    2700
    DLL MSFL GR SP CAL AMS
    2393
    2996
    FMS4 GR
    2396
    2828
    LDL CNL LSS CAL AMS
    905
    2872
    MWD - GR RES DIR
    884
    2993
    RFT AMS
    2551
    2660
    RFT AMS
    2551
    0
    RFT AMS
    2558
    0
    VSP
    1380
    2810

  • 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
    243.0
    36
    245.0
    0.00
    LOT
    INTERM.
    13 3/8
    906.0
    17 1/2
    922.0
    0.00
    LOT
    INTERM.
    9 5/8
    2394.0
    12 1/4
    2425.0
    1.63
    LOT
    OPEN HOLE
    3002.0
    8 1/2
    3002.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    170
    1.27
    WATER BASED
    27.12.1990
    850
    1.42
    13.0
    7.0
    WATER BASED
    20.11.1990
    1037
    1.42
    20.0
    9.0
    WATER BASED
    21.11.1990
    1341
    1.43
    21.0
    11.0
    WATER BASED
    22.11.1990
    1705
    1.46
    22.0
    10.0
    WATER BASED
    23.11.1990
    2070
    1.46
    19.0
    9.0
    WATER BASED
    27.11.1990
    2205
    1.48
    19.0
    9.0
    WATER BASED
    27.11.1990
    2239
    1.48
    23.0
    10.0
    WATER BASED
    27.11.1990
    2321
    1.48
    24.0
    8.0
    WATER BASED
    27.11.1990
    2379
    1.48
    23.0
    10.0
    WATER BASED
    28.11.1990
    2419
    1.47
    20.0
    8.0
    WATER BASED
    30.11.1990
    2419
    1.47
    18.0
    9.0
    WATER BASED
    04.12.1990
    2419
    1.48
    24.0
    11.0
    WATER BASED
    29.11.1990
    2422
    1.47
    19.0
    11.0
    WATER BASED
    04.12.1990
    2422
    1.44
    18.0
    9.0
    WATER BASED
    04.12.1990
    2425
    1.47
    21.0
    9.0
    WATER BASED
    04.12.1990
    2480
    1.27
    17.0
    6.0
    WATER BASED
    05.12.1990
    2553
    1.27
    18.0
    9.0
    WATER BASED
    10.12.1990
    2582
    1.27
    17.0
    7.0
    WATER BASED
    10.12.1990
    2652
    1.27
    17.0
    7.0
    WATER BASED
    10.12.1990
    2665
    1.27
    14.0
    8.0
    WATER BASED
    10.12.1990
    2671
    1.27
    14.0
    WATER BASED
    10.12.1990
    2973
    1.27
    14.0
    6.0
    WATER BASED
    12.12.1990
    3002
    1.27
    14.0
    6.0
    WATER BASED
    13.12.1990
    3002
    1.33
    15.0
    10.0
    WATER BASED
    14.12.1990
    3002
    1.33
    15.0
    10.0
    WATER BASED
    18.12.1990
    3002
    1.33
    15.0
    11.0
    WATER BASED
    18.12.1990
    3002
    1.27
    12.0
    9.0
    WATER BASED
    18.12.1990
    3002
    1.27
    11.0
    9.0
    WATER BASED
    18.12.1990
    3002
    1.27
    10.0
    9.0
    WATER BASED
    19.12.1990
    3002
    1.27
    11.0
    10.0
    WATER BASED
    27.12.1990
    3002
    1.27
    12.0
    9.0
    WATER BASED
    27.12.1990
    3002
    1.27
    14.0
    6.0
    WATER BASED
    13.12.1990
    3002
    1.27
    11.0
    10.0
    WATER BASED
    21.12.1990

  • Pressure plots
    Pressure plots
    The pore pressure data is sourced from well logs if no other source is specified. In some wells where pore pressure logs do not exist, information from Drill stem tests and kicks have been used. The data has been reported to the NPD, and further processed and quality controlled by IHS Markit.
    Pressure plots
    Document name
    Document format
    Document size [MB]
    pdf
    0.22