Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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24.11.2024 - 01:27
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6306/10-1

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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.
    6306/10-1
    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.
    NORWEGIAN SEA
    Well name
    Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    6306/10-1
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    NMI-822 & SP. 380
    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.
    A/S Norske Shell
    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.
    649-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.
    102
    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,
    07.09.1990
    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.
    17.12.1990
    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.
    17.12.1992
    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.
    30.06.2005
    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.
    OIL/GAS 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.
    83.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3187.0
    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).
    3183.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    6.9
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    114
    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.
    PRE-DEVONIAN
    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.
    BASEMENT
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    63° 9' 26.32'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    6° 19' 41.45'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7006088.05
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    365416.35
    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.
    1551

  • Wellbore history
    General
    Well 6306/10-1 was designed to drill the Skalmen prospect, a structural closure located at the northern apex of the Gossa High in block 6306/10. Amplitude anomalies was seen at 280-, 300-, 400-, 1200 to 1300-, and 2200- 2400 ms. The primary objective of the well was to test the hydrocarbon potential of Early Jurassic and Pre-Jurassic sequences, believed to be developed in a sandy facies of deltaic/fluvial origin. Secondary objective was to test potential reservoir developments in the Cretaceous and the Late Jurassic within dip-closure. A third objective was to test the hydrocarbon potential of Paleocene sands. The well should be drilled some 250-300 m into rocks of Pre-Jurassic age and would penetrate the primary objective some 300 m down-dip from the structural culmination.
    Operations and results
    Wildcat well 6306/10-1 was spudded with the semi-submersible installation Dyvi Stena on 7 September 1990 and drilled to TD at 3187 m in basement rocks. Shallow gas was not observed. Overcompacted sediments and boulders caused some problems, and the well had to be re-spudded several times. Bad weather caused some delay in the drilling procedure, as the string was temporary hung off several times. The well was drilled with Bentonite and seawater down to 610 m and with PAC/gypsum mud from 610m to TD.
    The well encountered close to 150 m of Paleocene Egga sand at 1138 m. Some sand developments were seen also in an Intra-Kvitnos Unit at 1825 m and in a 7 m thick Lysing Formation at 1992 m. The well penetrated a hiatus from Aptian to Early Callovian at 2692 m. The Middle Jurassic section from 2692 m to 2980 m contained about 60 m net sand with relatively low porosities and poor permeabilities, based on petrophysical log evaluation. The logs also showed that this section was gas bearing. Shows were recorded in the Egga Informal unit from 1142 m to 1180 m, in sandstone stringers in the interval 1992 m to 2470 m in the Lysing and Lange Formation, in the Middle Jurassic Viking and Fangst Groups from 2700 m to 2980 m, and on sidewall cores taken in metamorphic basement. Production testing of the Jurassic interval and the basement produced small volumes of gas at very low rates from the Jurassic, while the basement produced no formation fluid to surface.
    Various laboratories conducted extensive organic geochemical analyses in this well. These could confirm migrant hydrocarbons (shows) in the Egga sand and in the Middle Jurassic. The Egga hydrocarbons were severely biodegraded, but appeared to originate from a very early mature source. The Middle Jurassic shows and the DST oil showed variable fingerprints, but a more or less waxy, terrestrial nature was interpreted in many samples. The Middle Jurassic contained silty shales in the upper part (Melke) and more coaly shales and coals in the lower part (Garn). Both constitute excellent source rocks for gas and oil. The well is mature for oil generation (%Ro = 0.5) from ca 2200 m depth to TD.
    FMT pressure surveys gave a clear water gradient in Egga sand. No gradient could be established over the Jurassic and basement sections. FMT Fluid sampling in the Jurassic gave only mud filtrate. A total of 5 conventional cores were cut in the well: two in the Egga sand, one in the Melke Formation, one in the Garn Formation, and one in basement rock.
    The well was permanently abandoned with shows on 17 December 1990.
    Testing
    Two DST tests were carried out. No 1 perforated from 2995 - to 3187 m in basement. This test did not produce any formation fluid to surface. No 2 perforated from 2716 - to 2827 m in Jurassic rocks. It flowed gas at very low rates of some 1500 Sm3/d. Upon abandonment of the test the tubing content was circulated out. This indicated that condensate and some formation water had been produced (some 1 m3 of condensate and some 4 m3 of water, 13000 ppm C1-).

  • 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]
    620.00
    3169.00

  • 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
    1144.0
    1170.0
    [m ]
    2
    1172.0
    1198.7
    [m ]
    3
    2747.0
    2758.3
    [m ]
    4
    2880.0
    2888.0
    [m ]
    5
    3156.0
    3159.7
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    75.7
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 1144-1149m
    Core photo at depth: 1149-1154m
    Core photo at depth: 1154-1159m
    Core photo at depth: 1159-1164m
    Core photo at depth: 1164-1169m
    1144-1149m
    1149-1154m
    1154-1159m
    1159-1164m
    1164-1169m
    Core photo at depth: 1169-1174m
    Core photo at depth: 1174-1179m
    Core photo at depth: 1179-1184m
    Core photo at depth: 1184-1189m
    Core photo at depth: 1189-1194m
    1169-1174m
    1174-1179m
    1179-1184m
    1184-1189m
    1189-1194m
    Core photo at depth: 1194-1198m
    Core photo at depth: 2747-2752m
    Core photo at depth: 2752-2757m
    Core photo at depth: 2757-2758m
    Core photo at depth: 2880-2885m
    1194-1198m
    2747-2752m
    2752-2757m
    2757-2758m
    2880-2885m
    Core photo at depth: 2885-2888m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    2885-2888m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1145.0
    [m]
    C
    RRI
    1145.8
    [m]
    C
    RRI
    1147.0
    [m]
    C
    RRI
    1148.4
    [m]
    C
    RRI
    1150.0
    [m]
    C
    RRI
    1157.9
    [m]
    C
    RRI
    1159.1
    [m]
    C
    RRI
    1165.2
    [m]
    C
    RRI
    1172.1
    [m]
    C
    RRI
    1177.2
    [m]
    C
    RRI
    1184.8
    [m]
    C
    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
    DST2
    2716.00
    2827.00
    11.12.1990 - 00:00
    YES

  • Lithostratigraphy

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    4.35
    pdf
    2.70

  • 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
    45.22

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    2967
    3158
    0.0
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    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

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBIL GR
    2995
    3184
    CBL VDL
    0
    1498
    CBL VDL GR
    2480
    2978
    CND CNL GR CAL
    603
    1495
    CND CNL GR CAL
    1498
    2631
    CND CNL GR SPL
    2995
    3184
    CND CNL SPL CAL
    2642
    3141
    DIFL AC SP GR
    603
    1495
    DIFL AC SP GR
    1498
    2631
    DIFL AC SP GR
    2642
    3141
    DIFL AC SP GR
    2995
    3184
    DIPMETER
    2647
    3137
    DLL MLL GR
    2642
    3042
    DLL MLL GR
    2995
    3184
    DLL MSFL GR
    1075
    1325
    FMT GR
    1138
    1280
    FMT GR
    1828
    1849
    FMT GR
    1828
    1849
    FMT GR
    2721
    3115
    MWD - GR RES DIR
    100
    3074
    RSCT GR
    3101
    3139
    SWC GR
    614
    1477
    SWC GR
    1524
    2610
    SWC GR
    2660
    3107
    VELOCITY
    614
    3175
    VSP GR
    870
    3140

  • 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
    169.0
    36
    171.0
    0.00
    LOT
    INTERM.
    20
    603.0
    26
    605.0
    1.87
    LOT
    INTERM.
    13 3/8
    1499.0
    17 1/2
    1501.0
    1.80
    LOT
    INTERM.
    9 5/8
    2644.0
    12 1/4
    2647.0
    2.20
    LOT
    LINER
    7
    3187.0
    8 1/2
    3187.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    121
    0.00
    100.0
    WATER BASED
    10.09.1990
    175
    0.00
    100.0
    WATER BASED
    10.09.1990
    610
    0.00
    100.0
    WATER BASED
    13.09.1990
    610
    0.00
    100.0
    WATER BASED
    17.09.1990
    610
    0.00
    100.0
    WATER BASED
    17.09.1990
    610
    0.00
    100.0
    WATER BASED
    17.09.1990
    610
    0.00
    100.0
    WATER BASED
    17.09.1990
    610
    1.30
    60.0
    15.0
    WATER BASED
    20.09.1990
    610
    0.00
    100.0
    WATER BASED
    14.09.1990
    1031
    1.30
    52.0
    17.0
    WATER BASED
    20.09.1990
    1144
    1.30
    51.0
    18.0
    WATER BASED
    24.09.1990
    1144
    1.30
    51.0
    18.0
    WATER BASED
    24.09.1990
    1172
    1.30
    53.0
    12.0
    WATER BASED
    24.09.1990
    1200
    1.30
    51.0
    12.0
    WATER BASED
    25.09.1990
    1328
    1.30
    48.0
    13.0
    WATER BASED
    26.09.1990
    1478
    1.30
    50.0
    7.0
    WATER BASED
    26.09.1990
    1510
    1.30
    68.0
    10.0
    WATER BASED
    28.09.1990
    1510
    1.30
    68.0
    10.0
    WATER BASED
    01.10.1990
    1510
    1.30
    68.0
    10.0
    WATER BASED
    01.10.1990
    1510
    1.30
    98.0
    17.0
    WATER BASED
    01.10.1990
    1510
    1.30
    92.0
    5.0
    WATER BASED
    02.10.1990
    1554
    1.20
    41.0
    5.0
    WATER BASED
    03.10.1990
    1850
    1.20
    44.0
    6.0
    WATER BASED
    04.10.1990
    1914
    1.21
    42.0
    5.0
    WATER BASED
    04.10.1990
    1990
    1.21
    42.0
    17.0
    WATER BASED
    05.10.1990
    2045
    1.21
    45.0
    6.0
    WATER BASED
    08.10.1990
    2132
    1.25
    45.0
    6.0
    WATER BASED
    08.10.1990
    2133
    1.25
    45.0
    6.0
    WATER BASED
    08.10.1990
    2133
    1.25
    44.0
    6.0
    WATER BASED
    09.10.1990
    2133
    1.25
    44.0
    6.0
    WATER BASED
    10.10.1990
    2133
    1.25
    42.0
    5.0
    WATER BASED
    11.10.1990
    2133
    1.25
    42.0
    5.0
    WATER BASED
    12.10.1990
    2133
    1.25
    42.0
    6.0
    WATER BASED
    15.10.1990
    2133
    1.25
    46.0
    6.0
    WATER BASED
    15.10.1990
    2316
    1.25
    53.0
    7.0
    WATER BASED
    15.10.1990
    2414
    1.25
    49.0
    7.0
    WATER BASED
    16.10.1990
    2497
    1.25
    48.0
    6.0
    WATER BASED
    17.10.1990
    2595
    1.25
    49.0
    8.0
    WATER BASED
    18.10.1990
    2644
    1.35
    63.0
    12.0
    WATER BASED
    29.10.1990
    2644
    1.35
    63.0
    12.0
    WATER BASED
    25.10.1990
    2655
    1.25
    47.0
    7.0
    WATER BASED
    22.10.1990
    2655
    1.25
    47.0
    7.0
    WATER BASED
    22.10.1990
    2655
    1.25
    47.0
    7.0
    WATER BASED
    22.10.1990
    2655
    1.35
    46.0
    8.0
    WATER BASED
    23.10.1990
    2655
    1.35
    63.0
    11.0
    WATER BASED
    23.10.1990
    2683
    1.35
    50.0
    6.0
    WATER BASED
    29.10.1990
    2707
    1.35
    50.0
    6.0
    WATER BASED
    29.10.1990
    2747
    1.55
    49.0
    6.0
    WATER BASED
    29.10.1990
    2783
    1.60
    53.0
    8.0
    WATER BASED
    30.10.1990
    2859
    1.60
    52.0
    8.0
    WATER BASED
    31.10.1990
    2876
    1.60
    53.0
    8.0
    WATER BASED
    31.10.1990
    2889
    1.60
    59.0
    9.0
    WATER BASED
    01.11.1990
    2908
    1.60
    61.0
    10.0
    WATER BASED
    02.11.1990
    2950
    1.58
    66.0
    10.0
    WATER BASED
    10.12.1990
    2950
    1.58
    66.0
    10.0
    WATER BASED
    10.12.1990
    2950
    1.58
    66.0
    10.0
    WATER BASED
    10.12.1990
    2950
    1.58
    66.0
    10.0
    WATER BASED
    12.12.1990
    2950
    1.58
    65.0
    10.0
    WATER BASED
    13.12.1990
    2950
    1.58
    65.0
    9.0
    WATER BASED
    14.12.1990
    2950
    1.58
    65.0
    9.0
    WATER BASED
    17.12.1990
    2950
    1.58
    66.0
    11.0
    WATER BASED
    10.12.1990
    2950
    1.58
    66.0
    10.0
    WATER BASED
    11.12.1990
    2950
    1.58
    62.0
    9.0
    WATER BASED
    17.12.1990
    2965
    1.60
    52.0
    6.0
    WATER BASED
    05.11.1990
    2976
    1.60
    54.0
    7.0
    WATER BASED
    05.11.1990
    3019
    1.60
    53.0
    7.0
    WATER BASED
    05.11.1990
    3061
    1.60
    54.0
    7.0
    WATER BASED
    07.11.1990
    3074
    1.60
    56.0
    7.0
    WATER BASED
    08.11.1990
    3124
    1.60
    56.0
    7.0
    WATER BASED
    09.11.1990
    3141
    1.60
    62.0
    9.0
    WATER BASED
    19.11.1990
    3141
    1.60
    57.0
    8.0
    WATER BASED
    12.11.1990
    3141
    1.60
    57.0
    8.0
    WATER BASED
    12.11.1990
    3141
    1.60
    57.0
    8.0
    WATER BASED
    12.11.1990
    3141
    1.60
    60.0
    9.0
    WATER BASED
    13.11.1990
    3141
    1.60
    60.0
    9.0
    WATER BASED
    14.11.1990
    3141
    1.60
    60.0
    9.0
    WATER BASED
    15.11.1990
    3141
    1.60
    60.0
    9.0
    WATER BASED
    16.11.1990
    3141
    1.60
    63.0
    9.0
    WATER BASED
    19.11.1990
    3141
    1.60
    63.0
    9.0
    WATER BASED
    19.11.1990
    3141
    1.60
    53.0
    7.0
    WATER BASED
    20.11.1990
    3141
    1.60
    60.0
    8.0
    WATER BASED
    21.11.1990
    3141
    1.60
    60.0
    8.0
    WATER BASED
    22.11.1990
    3141
    1.55
    60.0
    9.0
    WATER BASED
    26.11.1990
    3158
    1.55
    68.0
    8.0
    WATER BASED
    26.11.1990
    3167
    1.55
    82.0
    7.0
    WATER BASED
    26.11.1990
    3182
    1.55
    82.0
    6.0
    WATER BASED
    26.11.1990
    3187
    1.55
    82.0
    7.0
    WATER BASED
    27.11.1990
    3187
    1.55
    84.0
    13.0
    WATER BASED
    28.11.1990
    3187
    1.55
    84.0
    13.0
    WATER BASED
    30.11.1990
    3187
    1.55
    97.0
    12.0
    WATER BASED
    04.12.1990
    3187
    1.55
    94.0
    12.0
    WATER BASED
    04.12.1990
    3187
    1.55
    88.0
    11.0
    WATER BASED
    04.12.1990
    3187
    1.55
    84.0
    10.0
    WATER BASED
    04.12.1990
    3187
    1.55
    83.0
    9.0
    WATER BASED
    04.12.1990
    3187
    1.55
    68.0
    13.0
    WATER BASED
    05.12.1990
    3187
    1.55
    84.0
    13.0
    WATER BASED
    30.11.1990

  • 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
    0.28