Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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6407/2-3

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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.
    6407/2-3
    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).
    APPRAISAL
    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.
    NORWEGIAN 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.
    6407/2-3
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    SG 8571 - 296 SP. 520
    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.
    Saga Petroleum ASA
    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.
    531-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,
    07.11.1986
    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.
    23.01.1987
    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.
    23.01.1989
    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.
    09.03.2009
    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.
    GAS/CONDENSATE
    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
    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.
    GARN 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.
    MIDDLE 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.
    ILE FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    26.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    250.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3050.0
    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).
    3050.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    10.3
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    104
    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.
    ÅRE FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    64° 56' 1.39'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    7° 39' 53.04'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7201913.99
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    436877.75
    UTM zone
    Universal Transverse Mercator zone. Examples of legal values: 31, 32, 33, 34.
    32
    NPDID wellbore
    Norwegian Offshore Directorate's unique id for the wellbore.
    935

  • Wellbore history
    General
    Well 6407/2-3 was drilled down dip on the Delta structure on the southern fault compartment of the Midgard Field off shore mid Norway. The primary objectives were to test for hydrocarbons in the Middle Jurassic Fangst Group, and establish the hydrocarbon contact. Secondary objectives were testing the thickness and facies development of reservoir units in response to growth faulting. Shallow gas was expected at several levels due to experience from nearby wells. Fangst Group was prognosed to come in at 2417 m, gas/oil contact at 2514 m, and the oil/water contact at 2525 m. TD was expected to be 3050 m.
    Operations and results
    Well 6407/2-3 was spudded with the semi-submersible installation Treasure Saga on 7 November 1986 and drilled to TD at 3050 m in Early Jurassic sediments of the Åre Formation. Gas peaks above 1% gas value were observed at 532 m, 590 m, 630 m, 755 m, and 802 m, the two latter showing the highest values at approximately 1.8%. The whole section was drilled using relatively high mud weights around 1.15 g/cm, which makes the recorded gas values significant. While tripping out at 2645 m prior to logging, the string got stuck. After nine days of fishing it was decided to sidetrack. The 9/58" casing was set at 2371 m and the sidetrack was kicked of at 2387 m. The well was drilled with spud mud down to 915 m and with gypsum/polymer mud from 915 m to 2645 m where the pipe stuck. No wire line logs were run in the interval 2432 - 2465 in this hole, only MWD. The final 8 1/2" sidetrack from 2371 m to TD was drilled with gel mud.
    The Fangst Group came in at 2427 m, ten meters below prognosis. It was gas-filled down to a gas/water contact at 2523 m (2521 m TVD RKB). No oil leg could be seen. No shows were seen in cuttings, but poor shows with good hydrocarbon odour were described on cores down to 2526 m in the Ile Formation. Fluorescence was very weak blue white and cut reaction very slow. Weak dark yellow brown fluorescence was recorded in sandstone in the Tilje core at 2760 - 2764 m. No stain, cut, or odour was associated with his fluorescence.
    Eight cores were cut from 2428 - 2573.1 m (recovered 142.8 m, 96.5%) in the Fangst Group and across the GWC contact. Down to the GWC it consisted of two sandstone units (Garn and Ile Formations) separated by one silty shale zone (the Not Formation). These cores were cut in the original hole, before side tracking. Core number 9 was cut in the side track hole from 2741 - 2769 m in the Tilje Formation (recovered 28 m, 100%). The lithology was sandstone interlaminated with shale. Porosity was predominantly poor. Segregated fluid samples were taken at 2428, 2430, and 2510.5 m.
    The well was permanently abandoned on 23 January 1987 as a gas/condensate discovery.
    Testing
    Two production tests were carried out and both produced a lean gas similar to what is found in the rest of the Midgard Field.
    Test No. 1 (2508.7 - 2518.2 m RKB, 2480.7 - 2490.2 TVD m MSL) perforated the Ile Formation and produced gas at a maximum rate of 1.285.000 Sm3 /day through a 38.1 mm choke at a well head pressure of 88 bar. The condensate/gas ratio was 0.000211 Sm3/Sm3 (GOR = 4740 Sm3/Sm3). The down-hole temperature recorded in the test was 91.8 deg C. API gravity of the dead condensate was 49.3 deg.
    Test No. 2 (2427.8 - 2435.8 m RKB, 2400.3 - 2408.3 TVD m MSL) perforated the Garn Formation and produced gas at a maximum rate of 1.320.500 Sm3 /day through a 38.1 mm choke at a well head pressure of 88.7 bar. The condensate/gas ratio was 0.000161 Sm3/Sm3 (GOR = 6210 Sm3/Sm3). The down-hole temperature recorded in the test was 89.2 deg C. API gravity of the dead condensate was 49.0 deg.

  • 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]
    400.00
    3049.00

  • 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
    2428.0
    2455.5
    [m ]
    2
    2455.5
    2476.5
    [m ]
    3
    2476.5
    2502.4
    [m ]
    4
    2502.5
    2511.0
    [m ]
    5
    2511.0
    2538.7
    [m ]
    6
    2538.5
    2556.5
    [m ]
    7
    2557.0
    2558.0
    [m ]
    8
    2558.0
    2571.6
    [m ]
    10
    2741.0
    2769.0
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    171.2
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 2428-2433m
    Core photo at depth: 2433-2438m
    Core photo at depth: 2438-2443m
    Core photo at depth: 2443-2448m
    Core photo at depth: 2448-2453m
    2428-2433m
    2433-2438m
    2438-2443m
    2443-2448m
    2448-2453m
    Core photo at depth: 2453-2457m
    Core photo at depth: 2457-2462m
    Core photo at depth: 2462-2467m
    Core photo at depth: 2467-2472m
    Core photo at depth: 2472-2476m
    2453-2457m
    2457-2462m
    2462-2467m
    2467-2472m
    2472-2476m
    Core photo at depth: 2476-2481m
    Core photo at depth: 2481-2486m
    Core photo at depth: 2486-2491m
    Core photo at depth: 2491-2496m
    Core photo at depth: 2496-2501m
    2476-2481m
    2481-2486m
    2486-2491m
    2491-2496m
    2496-2501m
    Core photo at depth: 2501-2505m
    Core photo at depth: 2505-2510m
    Core photo at depth: 2510-2515m
    Core photo at depth: 2515-2520m
    Core photo at depth: 2520-2525m
    2501-2505m
    2505-2510m
    2510-2515m
    2515-2520m
    2520-2525m
    Core photo at depth: 2525-2530m
    Core photo at depth: 2530-2535m
    Core photo at depth: 2535-2539m
    Core photo at depth: 2539-2544m
    Core photo at depth: 2544-2549m
    2525-2530m
    2530-2535m
    2535-2539m
    2539-2544m
    2544-2549m
    Core photo at depth: 2549-2554m
    Core photo at depth: 2554-2559m
    Core photo at depth: 2559-2564m
    Core photo at depth: 2564-2569m
    Core photo at depth: 2569-2743m
    2549-2554m
    2554-2559m
    2559-2564m
    2564-2569m
    2569-2743m
    Core photo at depth: 2743-2748m
    Core photo at depth: 2748-2753m
    Core photo at depth: 2753-2758m
    Core photo at depth: 2758-2763m
    Core photo at depth: 2763-2768m
    2743-2748m
    2748-2753m
    2753-2758m
    2758-2763m
    2763-2768m
    Core photo at depth: 2768-2769m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    2768-2769m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    409.0
    [m]
    SWC
    RRI
    429.5
    [m]
    SWC
    RRI
    452.5
    [m]
    SWC
    RRI
    468.0
    [m]
    SWC
    RRI
    473.5
    [m]
    SWC
    RRI
    489.1
    [m]
    SWC
    RRI
    500.0
    [m]
    SWC
    RRI
    528.0
    [m]
    SWC
    RRI
    544.5
    [m]
    SWC
    RRI
    570.0
    [m]
    SWC
    RRI
    593.0
    [m]
    SWC
    RRI
    615.0
    [m]
    SWC
    RRI
    632.0
    [m]
    SWC
    RRI
    640.5
    [m]
    SWC
    RRI
    668.5
    [m]
    SWC
    RRI
    689.5
    [m]
    SWC
    RRI
    695.9
    [m]
    SWC
    RRI
    708.6
    [m]
    SWC
    RRI
    730.0
    [m]
    SWC
    RRI
    752.0
    [m]
    SWC
    RRI
    775.2
    [m]
    SWC
    RRI
    807.0
    [m]
    SWC
    RRI
    837.0
    [m]
    SWC
    RRI
    862.0
    [m]
    SWC
    RRI
    899.0
    [m]
    SWC
    RRI
    972.0
    [m]
    SWC
    RRI
    1010.0
    [m]
    SWC
    RRI
    1030.0
    [m]
    SWC
    RRI
    1060.0
    [m]
    SWC
    RRI
    1190.0
    [m]
    SWC
    RRI
    1260.0
    [m]
    SWC
    RRI
    1290.0
    [m]
    SWC
    RRI
    1310.0
    [m]
    SWC
    RRI
    1340.0
    [m]
    SWC
    RRI
    1426.0
    [m]
    SWC
    RRI
    1470.0
    [m]
    SWC
    RRI
    1506.0
    [m]
    SWC
    RRI
    1553.0
    [m]
    SWC
    RRI
    1584.0
    [m]
    SWC
    RRI
    1630.0
    [m]
    SWC
    RRI
    1650.0
    [m]
    SWC
    RRI
    1856.0
    [m]
    SWC
    RRI
    1900.0
    [m]
    SWC
    RRI
    2070.0
    [m]
    SWC
    RRI
    2106.5
    [m]
    SWC
    RRI
    2150.5
    [m]
    SWC
    RRI
    2200.0
    [m]
    SWC
    RRI
    2232.0
    [m]
    SWC
    RRI
    2260.0
    [m]
    SWC
    RRI
    2280.0
    [m]
    SWC
    RRI
    2315.0
    [m]
    SWC
    RRI
    2323.0
    [m]
    SWC
    RRI
    2347.0
    [m]
    SWC
    RRI
    2360.0
    [m]
    SWC
    RRI
    2383.0
    [m]
    SWC
    RRI
    2398.0
    [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
    2518.20
    2508.70
    06.01.1987 - 16:10
    YES
    DST
    DST 2
    2427.80
    2435.80
    13.01.1987 - 13:30
    YES

  • Lithostratigraphy
    Lithostratigraphy
    Top depth [mMD RKB]
    Lithostrat. unit
    276
    1311
    1966
    1966
    2025
    2072
    2320
    2393
    2393
    2399
    2427
    2427
    2480
    2509
    2581
    2581
    2739
    2910

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.54
    pdf
    0.51
    pdf
    5.18

  • 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
    7.67
    pdf
    2.28

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    2518
    2509
    38.1
    2.0
    2436
    2428
    38.1
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    9.000
    17.000
    92
    2.0
    9.000
    17.000
    89
    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
    271
    1285000
    0.766
    0.705
    4740
    2.0
    213
    1321000
    0.768
    0.705
    6210

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    ACBL VDL
    684
    1952
    ACBL VDL BHC GR
    1690
    2610
    CDL
    900
    1953
    CNL CDL GR
    1952
    2431
    CNL LDC SPECTRA GR
    2368
    3051
    COREGUN
    920
    1935
    COREGUN
    1952
    2429
    COREGUN
    2369
    3047
    DIFL LSBHC GR
    399
    913
    DIFL LSBHC GR
    900
    1969
    DIFL LSBHC GR
    1952
    2431
    DIFL LSBHC GR
    2369
    3049
    DIPLOG
    1952
    2429
    DIPLOG
    2368
    3047
    DLL MLL GR
    2368
    3047
    FMT
    2428
    2741
    MWD - GR RES DIR
    399
    3047
    VSP
    384
    3006
    ZDENS
    2368
    3034

  • 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
    398.0
    36
    403.0
    0.00
    LOT
    SURF.COND.
    20
    900.0
    26
    915.0
    1.51
    LOT
    INTERM.
    13 3/8
    1954.0
    17 1/2
    2104.0
    1.83
    LOT
    INTERM.
    9 5/8
    2371.0
    12 1/4
    2645.0
    1.69
    LOT
    LINER
    7
    2625.0
    8 1/2
    3050.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    286
    1.06
    WATER BASED
    10.11.1986
    327
    1.06
    WATER BASED
    11.11.1986
    403
    1.06
    WATER BASED
    17.11.1986
    531
    1.13
    5.0
    19.2
    WATER BASED
    17.11.1986
    915
    1.14
    6.0
    17.3
    WATER BASED
    17.11.1986
    915
    1.18
    7.0
    19.2
    WATER BASED
    17.11.1986
    915
    1.20
    8.0
    14.4
    WATER BASED
    18.11.1986
    915
    1.10
    25.0
    16.8
    WATER BASED
    19.11.1986
    915
    1.10
    24.0
    15.9
    WATER BASED
    18.11.1986
    925
    1.18
    6.0
    17.3
    WATER BASED
    17.11.1986
    1119
    1.12
    15.0
    8.7
    WATER BASED
    20.11.1986
    1345
    1.15
    13.0
    5.8
    WATER BASED
    21.11.1986
    1770
    1.30
    18.0
    9.1
    WATER BASED
    24.11.1986
    1968
    1.45
    16.0
    5.3
    WATER BASED
    24.11.1986
    1968
    1.45
    20.0
    6.3
    WATER BASED
    24.11.1986
    1968
    1.45
    16.0
    5.3
    WATER BASED
    02.12.1986
    2104
    1.50
    28.0
    9.1
    WATER BASED
    02.12.1986
    2115
    1.58
    18.0
    6.3
    WATER BASED
    02.12.1986
    2115
    1.58
    19.0
    10.1
    WATER BASED
    02.12.1986
    2115
    1.58
    21.0
    9.1
    WATER BASED
    02.12.1986
    2115
    1.58
    24.0
    7.2
    WATER BASED
    02.12.1986
    2115
    1.58
    17.0
    8.2
    WATER BASED
    05.12.1986
    2115
    1.58
    15.0
    6.3
    WATER BASED
    08.12.1986
    2115
    1.58
    15.0
    6.8
    WATER BASED
    08.12.1986
    2115
    1.58
    15.0
    6.8
    WATER BASED
    09.12.1986
    2115
    1.58
    18.0
    6.8
    WATER BASED
    02.12.1986
    2228
    0.00
    16.0
    7.2
    WATER BASED
    13.01.1987
    2228
    0.00
    16.0
    6.8
    WATER BASED
    09.01.1987
    2288
    0.00
    16.0
    7.2
    WATER BASED
    12.01.1987
    2345
    0.00
    12.0
    6.8
    WATER BASED
    15.01.1987
    2371
    0.00
    15.0
    6.8
    WATER BASED
    22.12.1986
    2386
    1.58
    14.0
    6.8
    WATER BASED
    16.12.1986
    2386
    1.58
    14.0
    6.8
    WATER BASED
    17.12.1986
    2386
    1.27
    14.0
    5.3
    WATER BASED
    22.12.1986
    2387
    1.27
    15.0
    6.8
    WATER BASED
    22.12.1986
    2425
    0.00
    16.0
    7.2
    WATER BASED
    12.01.1987
    2505
    0.00
    14.0
    6.3
    WATER BASED
    22.12.1986
    2557
    1.58
    13.0
    6.8
    WATER BASED
    05.12.1986
    2573
    1.58
    13.0
    6.3
    WATER BASED
    05.12.1986
    2588
    0.00
    14.0
    6.8
    WATER BASED
    14.01.1987
    2640
    0.00
    15.0
    6.8
    WATER BASED
    09.01.1987
    2640
    0.00
    14.0
    4.8
    WATER BASED
    02.01.1987
    2640
    0.00
    15.0
    5.3
    WATER BASED
    05.01.1987
    2640
    0.00
    15.0
    5.3
    WATER BASED
    06.01.1987
    2640
    0.00
    14.0
    5.3
    WATER BASED
    08.01.1987
    2645
    1.48
    15.0
    7.7
    WATER BASED
    09.12.1986
    2645
    1.58
    15.0
    8.7
    WATER BASED
    11.12.1986
    2645
    1.58
    18.0
    8.2
    WATER BASED
    11.12.1986
    2645
    1.58
    17.0
    8.7
    WATER BASED
    10.12.1986
    2645
    1.58
    16.0
    7.2
    WATER BASED
    15.12.1986
    2645
    1.58
    16.0
    7.7
    WATER BASED
    16.12.1986
    2645
    1.58
    17.0
    6.3
    WATER BASED
    16.12.1986
    2645
    1.59
    15.0
    7.2
    WATER BASED
    16.12.1986
    2647
    0.00
    16.0
    7.7
    WATER BASED
    22.12.1986
    2741
    0.00
    17.0
    7.2
    WATER BASED
    29.12.1986
    2798
    0.00
    16.0
    7.7
    WATER BASED
    29.12.1986
    3036
    0.00
    19.0
    8.2
    WATER BASED
    29.12.1986
    3050
    0.00
    19.0
    7.7
    WATER BASED
    29.12.1986
    3050
    0.00
    16.0
    6.8
    WATER BASED
    02.01.1987
    3050
    0.00
    18.0
    6.8
    WATER BASED
    02.01.1987
    3050
    0.00
    19.0
    7.7
    WATER BASED
    02.01.1987
    3050
    0.00
    15.0
    5.3
    WATER BASED
    05.01.1987
    3050
    0.00
    16.0
    5.8
    WATER BASED
    05.01.1987

  • 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
    0.27