Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
10.11.2024 - 01:25
Time of last synchronization with Norwegian Offshore Directorate's internal systems

7324/10-1

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.
    7324/10-1
    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.
    BARENTS SEA
    Well name
    Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    7324/10-1
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    GLR 3-87-19B SP. 3290
    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.
    Den norske stats oljeselskap a.s
    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.
    609-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.
    78
    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,
    03.06.1989
    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.
    19.08.1989
    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.
    19.08.1991
    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.
    11.01.2005
    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.
    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.
    23.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    408.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2919.0
    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).
    2919.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    2.8
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    119
    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 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.
    HAVERT FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    73° 9' 49.45'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    24° 18' 47.62'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    8120918.38
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    413162.08
    UTM zone
    Universal Transverse Mercator zone. Examples of legal values: 31, 32, 33, 34.
    35
    NPDID wellbore
    Norwegian Offshore Directorate's unique id for the wellbore.
    1411

  • Wellbore history
    General
    Well 7324/10-1 was drilled on the Alpha structure in the Maud Basin on the Bjarmeland Platform. The main objective was to test the hydrocarbon potential in a prospect at the Base Anisian level (Top Klappmyss Formation). The secondary objective was to test sandstones below the Base Smithian level (Top Havert Formation). In addition the well should test the source rock potential in the Triassic, Base Snadd, and Base Kobbe Formations. Possible sand layers at 575 - and 695 m justified a shallow gas warning at these levels. Planned TD was at 3400 m in Late Permian.
    Operations and results
    Wildcat well 7324/10-1 was spudded with the semi-submersible rig Ross Rig 3 June 1989 and drilled to TD at 2919 m in the Early Triassic Havert Formation. TD was set approximately 500 m higher than prognosed due to lost circulation problems in the interval 1800 m to 2626 m. The well was drilled with seawater down to 558 m, with gypsum / polymer from 558 m to 2289 m, and with gel / lignosulphonate from 2289 m to TD. No shallow gas was encountered.
    Minor gas was encountered in the Kobbe Formation at 1607 m but the sandstones had very poor permeability and no RFT samples were collected. The main target at Base Anisian/Klappmyss Formation at 1767 m in the prognosis, proved to be an intra Anisian seismic marker encountered at 1822 m. At this level there was no reservoir developed, neither was there any reservoir developed at the new Anisian seismic marker on 2272 m. The secondary objective at top Havert Formation encountered at 2512 m had a limited reservoir developed. Shows were recorded in the Snadd Formation from 617 m to 692 m and 1150 m to 1186 m. Organic rich shales were encountered in Snadd, Kobbe, and Klappmyss Formations, but from organic geochemistry only a thin sequences in the Snadd Formation could be classified as good, possibly oil-prone source rocks. These were: a carbonaceous shale at 989 m and a thin clay stone sequence at 1603 m to 1607 m. At 2267 m at the base of the Kobbe Formation a third organic-rich sequence (TOC typically 2 ? 4 %) is encountered, but hydrogen index in this sequence indicate only gas prone kerogen at best, possibly due to advanced maturity. The well reaches oil-window maturity at ca 1000 m, the wet gas window is reached at ca 2200 m, and dry gas maturity is reached at ca 2700 m. Temperatures measured during well-logging indicate an average thermal gradient, from surface to TD, of ca 46 °C/km. Pore pressure is normal down to ca 1270 m. From 1270 m down to the organic rich shales at 2267 the pore pressure is abnormal. Below 2500 m the pressure starts to decrease. A total of five cores were cut in the well, and 450 sidewall cores were attempted but only 384 was recovered. One RFT fluid sample was taken at 570 m. The sample contained mud filtrate and formation water with no associated gas.
    The well was permanently abandoned 19 August 1989 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]
    560.00
    2917.00

  • 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
    1411.0
    1414.6
    [m ]
    2
    1659.0
    1667.3
    [m ]
    3
    1777.0
    1782.6
    [m ]
    4
    2640.2
    2640.5
    [m ]
    5
    2640.5
    2659.1
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    36.4
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 1411-1414m
    Core photo at depth: 1659-1664m
    Core photo at depth: 1664-1667m
    Core photo at depth: 1777-1782m
    Core photo at depth: 1782-1783m
    1411-1414m
    1659-1664m
    1664-1667m
    1777-1782m
    1782-1783m
    Core photo at depth: 2640-2641m
    Core photo at depth: 2640-2645m
    Core photo at depth: 2645-2650m
    Core photo at depth: 2650-2655m
    Core photo at depth: 2655-2659m
    2640-2641m
    2640-2645m
    2645-2650m
    2650-2655m
    2655-2659m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    499.0
    [m]
    SWC
    STATO
    508.0
    [m]
    SWC
    STATO
    517.0
    [m]
    SWC
    STATO
    528.0
    [m]
    SWC
    STATO
    537.0
    [m]
    SWC
    STATO
    547.0
    [m]
    SWC
    STATO
    550.0
    [m]
    SWC
    STATO
    552.0
    [m]
    SWC
    STATO
    554.0
    [m]
    SWC
    STATO
    563.0
    [m]
    SWC
    STATO
    567.0
    [m]
    SWC
    STATO
    573.0
    [m]
    SWC
    STATO
    582.0
    [m]
    SWC
    STATO
    599.0
    [m]
    SWC
    STATO
    615.0
    [m]
    SWC
    STATO
    633.0
    [m]
    SWC
    STATO
    667.0
    [m]
    SWC
    STATO
    676.5
    [m]
    SWC
    STATO
    686.0
    [m]
    SWC
    STATO
    698.0
    [m]
    SWC
    STATO
    767.0
    [m]
    SWC
    STATO
    783.5
    [m]
    SWC
    STATO
    814.5
    [m]
    SWC
    STATO
    835.0
    [m]
    SWC
    STATO
    858.0
    [m]
    SWC
    STATO
    888.0
    [m]
    SWC
    STATO
    924.0
    [m]
    SWC
    STATO
    947.0
    [m]
    SWC
    STATO
    976.0
    [m]
    SWC
    STATO
    1010.0
    [m]
    SWC
    STATO
    1033.0
    [m]
    SWC
    STATO
    1085.0
    [m]
    SWC
    STATO
    1108.0
    [m]
    SWC
    STATO
    1148.0
    [m]
    SWC
    STATO
    1168.0
    [m]
    SWC
    STATO
    1185.0
    [m]
    SWC
    STATO
    1204.0
    [m]
    SWC
    STATO
    1230.0
    [m]
    SWC
    STATO
    1253.0
    [m]
    SWC
    STATO
    1273.0
    [m]
    SWC
    STATO
    1284.0
    [m]
    SWC
    STATO
    1318.0
    [m]
    SWC
    STATO
    1335.0
    [m]
    SWC
    STATO
    1360.5
    [m]
    SWC
    STATO
    1394.0
    [m]
    SWC
    STATO
    1399.0
    [m]
    DC
    STATO
    1412.0
    [m]
    SWC
    STATO
    1412.0
    [m]
    C
    STATO
    1414.6
    [m]
    C
    STATO
    1433.0
    [m]
    SWC
    STATO
    1445.0
    [m]
    SWC
    STATO
    1465.0
    [m]
    SWC
    STATO
    1485.0
    [m]
    SWC
    STATO
    1508.0
    [m]
    SWC
    STATO
    1543.0
    [m]
    SWC
    STATO
    1561.0
    [m]
    SWC
    STATO
    1587.0
    [m]
    SWC
    STATO
    1605.5
    [m]
    SWC
    STATO
    1619.5
    [m]
    SWC
    STATO
    1640.0
    [m]
    SWC
    STATO
    1667.0
    [m]
    C
    STATO
    1671.5
    [m]
    SWC
    STATO
    1696.0
    [m]
    SWC
    STATO
    1733.0
    [m]
    SWC
    STATO
    1756.0
    [m]
    SWC
    STATO
    1783.0
    [m]
    C
    STATO
    1784.5
    [m]
    SWC
    STATO
    1802.0
    [m]
    SWC
    STATO
    1822.0
    [m]
    SWC
    STATO
    1834.0
    [m]
    SWC
    STATO
    1856.0
    [m]
    SWC
    STATO
    1912.0
    [m]
    DC
    STATO
    1925.0
    [m]
    SWC
    STATO
    1955.0
    [m]
    SWC
    STATO
    1979.0
    [m]
    SWC
    STATO
    2000.0
    [m]
    SWC
    STATO
    2027.0
    [m]
    SWC
    STATO
    2050.0
    [m]
    SWC
    STATO
    2070.0
    [m]
    SWC
    STATO
    2095.0
    [m]
    SWC
    STATO
    2118.0
    [m]
    SWC
    STATO
    2155.0
    [m]
    SWC
    STATO
    2183.0
    [m]
    SWC
    STATO
    2212.0
    [m]
    SWC
    STATO
    2245.0
    [m]
    SWC
    STATO
    2269.0
    [m]
    DC
    STATO
    2305.0
    [m]
    SWC
    STATO
    2345.0
    [m]
    SWC
    STATO
    2385.5
    [m]
    SWC
    STATO
    2386.0
    [m]
    DC
    STATO
    2434.0
    [m]
    DC
    STATO
    2469.0
    [m]
    SWC
    STATO
    2521.0
    [m]
    SWC
    STATO
    2551.0
    [m]
    DC
    STATO
    2557.5
    [m]
    SWC
    STATO
    2603.0
    [m]
    SWC
    STATO
    2637.0
    [m]
    SWC
    STATO
    2690.0
    [m]
    SWC
    STATO
    2732.0
    [m]
    SWC
    STATO
    2786.0
    [m]
    SWC
    STATO
    2805.0
    [m]
    DC
    STATO
    2833.0
    [m]
    DC
    STATO
    2876.0
    [m]
    DC
    STATO
    2918.0
    [m]
    DC
    STATO

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.48

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    1.36

  • 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
    31.71

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    AMS LDL CNL GR
    2325
    2607
    AMS SHDT
    1290
    2205
    AMS SHDT
    2325
    2607
    AMS SHDT
    2627
    2921
    CBL VDL GR
    554
    2575
    CST
    496
    556
    CST
    557
    936
    CST
    943
    1561
    CST
    1587
    1856
    CST
    1865
    2212
    CST
    2222
    2610
    CST
    2222
    2610
    CST
    2632
    2917
    CST
    2637
    2918
    DIL LSS GR SP
    493
    2917
    LDL CNL GR CAL
    554
    2920
    LDL GR CAL
    493
    557
    LSS VDL
    1550
    2212
    MWD GR RES DIR
    493
    2921
    NGT
    2627
    2920
    RFT HP
    570
    654
    RFT HP
    1607
    2185
    RFT HP
    2516
    2621
    SHDT
    554
    2921
    VSP
    554
    1530
    VSP
    1470
    2151
    VSP
    2150
    2910

  • 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
    494.0
    36
    497.0
    0.00
    LOT
    INTERM.
    20
    554.0
    26
    559.0
    1.35
    LOT
    INTERM.
    13 3/8
    1551.0
    17 1/2
    1570.0
    1.59
    LOT
    INTERM.
    9 5/8
    2216.0
    12 1/4
    2235.0
    1.60
    LOT
    LINER
    7
    2626.0
    8 1/2
    2627.0
    1.71
    LOT
    OPEN HOLE
    2919.0
    6
    2919.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    559
    1.18
    1000.0
    4.0
    WATER BASED
    08.06.1989
    560
    1.20
    1100.0
    4.5
    WATER BASED
    09.06.1989
    765
    1.20
    1300.0
    3.5
    WATER BASED
    12.06.1989
    784
    1.20
    1100.0
    3.5
    WATER BASED
    12.06.1989
    940
    1.20
    1100.0
    5.0
    WATER BASED
    22.08.1989
    990
    1.20
    1400.0
    3.5
    WATER BASED
    12.06.1989
    1184
    1.20
    1400.0
    3.5
    WATER BASED
    13.06.1989
    1342
    1.20
    1500.0
    3.5
    WATER BASED
    14.06.1989
    1411
    1.20
    1500.0
    3.5
    WATER BASED
    15.06.1989
    1415
    1.20
    1500.0
    3.0
    WATER BASED
    16.06.1989
    1477
    1.20
    1500.0
    4.5
    WATER BASED
    19.06.1989
    1500
    1.32
    1600.0
    3.0
    WATER BASED
    17.08.1989
    1570
    1.20
    1700.0
    4.0
    WATER BASED
    19.06.1989
    1570
    1.20
    1300.0
    3.5
    WATER BASED
    21.06.1989
    1570
    1.20
    1300.0
    3.5
    WATER BASED
    22.06.1989
    1666
    1.20
    1600.0
    4.0
    WATER BASED
    26.06.1989
    1749
    1.20
    1400.0
    4.0
    WATER BASED
    26.06.1989
    1781
    1.20
    1700.0
    4.0
    WATER BASED
    27.06.1989
    1834
    1.20
    1700.0
    5.0
    WATER BASED
    28.06.1989
    1900
    1.32
    1300.0
    2.0
    WATER BASED
    16.08.1989
    1965
    1.20
    1900.0
    4.5
    WATER BASED
    29.06.1989
    2022
    1.20
    1700.0
    5.0
    WATER BASED
    30.06.1989
    2148
    1.25
    2200.0
    5.0
    WATER BASED
    03.07.1989
    2235
    1.32
    1800.0
    5.5
    WATER BASED
    03.07.1989
    2235
    1.32
    2100.0
    6.5
    WATER BASED
    04.07.1989
    2235
    1.32
    2200.0
    7.5
    WATER BASED
    05.07.1989
    2235
    1.32
    2200.0
    6.0
    WATER BASED
    03.07.1989
    2235
    1.32
    1900.0
    6.0
    WATER BASED
    07.07.1989
    2238
    1.44
    1900.0
    6.5
    WATER BASED
    10.07.1989
    2269
    1.47
    2000.0
    5.0
    WATER BASED
    11.07.1989
    2296
    1.44
    2000.0
    6.5
    WATER BASED
    12.07.1989
    2423
    1.35
    2200.0
    4.0
    WATER BASED
    15.08.1989
    2434
    1.53
    1900.0
    6.0
    WATER BASED
    13.07.1989
    2434
    1.53
    1000.0
    20.5
    WATER BASED
    17.07.1989
    2434
    1.53
    1100.0
    9.0
    WATER BASED
    17.07.1989
    2434
    1.53
    1000.0
    23.5
    WATER BASED
    17.07.1989
    2500
    1.53
    1000.0
    7.5
    WATER BASED
    19.07.1989
    2500
    1.53
    1600.0
    9.0
    WATER BASED
    21.07.1989
    2500
    1.53
    1200.0
    4.0
    WATER BASED
    24.07.1989
    2500
    1.53
    1400.0
    4.5
    WATER BASED
    24.07.1989
    2500
    1.53
    1400.0
    16.3
    WATER BASED
    18.07.1989
    2500
    1.53
    2200.0
    3.5
    WATER BASED
    02.08.1989
    2500
    1.53
    1500.0
    3.0
    WATER BASED
    31.07.1989
    2500
    1.53
    1500.0
    3.0
    WATER BASED
    31.07.1989
    2500
    1.53
    1900.0
    4.0
    WATER BASED
    31.07.1989
    2500
    1.53
    1900.0
    4.0
    WATER BASED
    01.08.1989
    2614
    1.53
    1400.0
    4.5
    WATER BASED
    24.07.1989
    2614
    1.53
    1700.0
    7.5
    WATER BASED
    25.07.1989
    2614
    1.53
    1600.0
    6.0
    WATER BASED
    26.07.1989
    2617
    1.53
    1300.0
    4.5
    WATER BASED
    27.07.1989
    2627
    1.53
    1400.0
    3.5
    WATER BASED
    28.07.1989
    2627
    1.53
    2100.0
    3.5
    WATER BASED
    03.08.1989
    2628
    1.35
    1000.0
    7.0
    WATER BASED
    07.08.1989
    2640
    1.35
    1800.0
    7.0
    WATER BASED
    08.08.1989
    2659
    1.35
    1800.0
    3.5
    WATER BASED
    09.08.1989
    2773
    1.35
    1700.0
    4.0
    WATER BASED
    10.08.1989
    2870
    1.35
    1600.0
    3.5
    WATER BASED
    11.08.1989
    2919
    1.35
    1800.0
    4.0
    WATER BASED
    14.08.1989
    2919
    1.35
    1800.0
    3.5
    WATER BASED
    14.08.1989
    2919
    1.35
    1800.0
    3.5
    WATER BASED
    14.08.1989

  • Thin sections at the Norwegian Offshore Directorate
    Thin sections at the Norwegian Offshore Directorate
    Depth
    Unit
    1664.75
    [m ]
    1664.50
    [m ]
    1659.80
    [m ]
    2640.22
    [m ]

  • 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
    0.26