Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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04.11.2024 - 01:25
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31/2-6

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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.
    31/2-6
    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.
    NORTH 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.
    31/2-6
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    LINE 79-406 & SP185
    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.
    296-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.
    89
    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,
    21.07.1981
    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.
    17.10.1981
    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.
    17.10.1983
    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.
    06.06.2006
    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.
    OIL/GAS
    Discovery wellbore
    Indicator which tells if the wellbore made a new discovery. Legal values: YES, NO. Prior to press-release or other information regarding drilling results, the indicator will be “NO” as a default.
    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.
    LATE 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.
    SOGNEFJORD FM
    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.
    343.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    1760.0
    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).
    1754.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    1.25
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    73
    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.
    MIDDLE 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.
    FENSFJORD FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    60° 54' 13.57'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    3° 38' 49.53'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6752401.91
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    535105.69
    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.
    399

  • Wellbore history
    General
    Well 31/2-6 is located in a fault block north-east on the main Troll structure, approximately 8 km NNE of 31/2-3. The main objective of the well was to test the north-eastern margin of the Troll structure and to prove hydrocarbon communication between block 31/2 and 31/3. The well location was picked to test the oil zone in a good sand reservoir. A second objective was to get reliable geologic tie to the seismic reflectors to allow for accurate lateral extrapolation of well data. Planned TD was 2500 m in Triassic sediments.
    The well is Reference Well for the Sele Formation.
    Operations and results
    Appraisal well 31/2-6 was spudded with the semi-submersible installation Borgny Dolphin on and drilled to TD at 1760 m in the Late Jurassic Formation. The 9 5/8" casing collapsed at 771 m and was cut and retrieved from 760 m. As a result of this, well 31/2-6 was not deepened to the Triassic. The well was drilled with seawater gel down to 614 m and with KCl polymer mud from 614 m to TD.
    Well 31/2-6 proved a similar hydrocarbon accumulation in this northern fault block area to that of the main field accumulation tested by wells 31/2-1,2,3 and 4. The well encountered the Sognefjord Formation at 1492 m. The Formation held a 79.4 m gross gas column underlain by a 10.3 m oil column. The GOC at 1571.4 m and the OWC was at 1582.2 m. Well 31/2-6 confirmed the overall interpretation of the flatspot as a direct hydrocarbon indicator. Oils shows were recorded on cores from 1504 m to 1601 m. In addition, cuttings gave patchy shows in the interval from 1710 m to 1758 m. Sidewall cores from this interval did not confirm shows in the latter interval.
    Coring commenced at 1504.4 m and terminated at 1632.05 m, within the Sognefjord Formation. Thus 127.65 m of core was cut from which 123.65 m (97%) was recovered. An RFT gas sample was taken at 1518 m as a backup until samples could be obtained from the subsequent production test. No sample was attempted in the oil zone because of the badly washed out hole.
    The well was permanently abandoned on 17 October 1981 as a gas and oil appraisal.
    Testing
    Production testing was carried out in both the oil and gas zones. The oil zone from 1576 m to 1579 m produced up to 151 Sm3 bbl/day of 27 °API oil with a GOR of up to 267 Sm3/Sm3. Maximum temperature recorded was 65.6 deg. C. The gas zone from 1518 m to 1537 m produced up to 1699000 Sm3 gas/day with a condensate/gas ratio of ca 0.00002 Sm3/Sm3 (GOR = ca 50000 Sm3/Sm3). The maximum recorded temperature in this test was 62.8 deg. C. The DST temperatures gives a temperature gradient above the Troll reservoir of ca 51 deg C /km, which is unusually high compared to the average for the Norwegian continental shelf.

  • 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]
    480.00
    1749.00

  • 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
    1504.4
    1514.0
    [m ]
    2
    1514.0
    1532.5
    [m ]
    3
    1532.5
    1550.9
    [m ]
    4
    1551.0
    1555.8
    [m ]
    5
    1557.5
    1575.8
    [m ]
    6
    1576.0
    1582.4
    [m ]
    7
    1583.9
    1602.3
    [m ]
    8
    1602.8
    1618.7
    [m ]
    9
    1618.8
    1632.3
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    123.7
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 1504-1509m
    Core photo at depth: 1509-1514m
    Core photo at depth: 1514-1519m
    Core photo at depth: 1519-1524m
    Core photo at depth: 1524-1530m
    1504-1509m
    1509-1514m
    1514-1519m
    1519-1524m
    1524-1530m
    Core photo at depth: 1530-1532m
    Core photo at depth: 1532-1537m
    Core photo at depth: 1537-1543m
    Core photo at depth: 1543-1548m
    Core photo at depth: 1548-1550m
    1530-1532m
    1532-1537m
    1537-1543m
    1543-1548m
    1548-1550m
    Core photo at depth: 1551-1555m
    Core photo at depth: 1557-1562m
    Core photo at depth: 1562-1568m
    Core photo at depth: 1568-1573m
    Core photo at depth: 1573-1575m
    1551-1555m
    1557-1562m
    1562-1568m
    1568-1573m
    1573-1575m
    Core photo at depth: 1576-1581m
    Core photo at depth: 1581-1582m
    Core photo at depth: 1583-1589m
    Core photo at depth: 1589-1594m
    Core photo at depth: 1594-1600m
    1576-1581m
    1581-1582m
    1583-1589m
    1589-1594m
    1594-1600m
    Core photo at depth: 1600-1602m
    Core photo at depth: 1602-1608m
    Core photo at depth: 1608-1613m
    Core photo at depth: 1613-1618m
    Core photo at depth: 1618-1624m
    1600-1602m
    1602-1608m
    1608-1613m
    1613-1618m
    1618-1624m
    Core photo at depth: 1624-1629m
    Core photo at depth: 1629-1632m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    1624-1629m
    1629-1632m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    610.0
    [m]
    DC
    GEOCH
    640.0
    [m]
    DC
    GEOCH
    670.0
    [m]
    DC
    GEOCH
    700.0
    [m]
    DC
    GEOCH
    730.0
    [m]
    DC
    GEOCH
    760.0
    [m]
    DC
    GEOCH
    790.0
    [m]
    DC
    GEOCH
    820.0
    [m]
    DC
    GEOCH
    850.0
    [m]
    DC
    GEOCH
    880.0
    [m]
    DC
    GEOCH
    910.0
    [m]
    DC
    GEOCH
    940.0
    [m]
    DC
    GEOCH
    970.0
    [m]
    DC
    GEOCH
    1000.0
    [m]
    DC
    GEOCH
    1030.0
    [m]
    DC
    GEOCH
    1060.0
    [m]
    DC
    GEOCH
    1090.0
    [m]
    DC
    GEOCH
    1120.0
    [m]
    DC
    GEOCH
    1150.0
    [m]
    DC
    GEOCH
    1180.0
    [m]
    DC
    GEOCH
    1212.0
    [m]
    DC
    GEOCH
    1242.0
    [m]
    DC
    GEOCH
    1272.0
    [m]
    DC
    GEOCH
    1302.0
    [m]
    DC
    GEOCH
    1326.0
    [m]
    DC
    GEOCH
    1353.0
    [m]
    DC
    GEOCH
    1380.0
    [m]
    DC
    GEOCH
    1407.0
    [m]
    DC
    GEOCH
    1434.0
    [m]
    DC
    GROCH
    1452.0
    [m]
    DC
    GEOCH
    1461.0
    [m]
    DC
    GEOCH
    1470.0
    [m]
    DC
    GEOCH
    1479.0
    [m]
    DC
    GEOCH
    1482.0
    [m]
    SWC
    SHELL
    1483.0
    [m]
    SWC
    SHELL
    1485.0
    [m]
    SWC
    SHELL
    1487.0
    [m]
    SWC
    SHELL
    1488.8
    [m]
    SWC
    SHELL
    1495.0
    [m]
    SWC
    SHELL
    1495.9
    [m]
    SWC
    SHELL
    1500.0
    [m]
    SWC
    SHELL
    1503.0
    [m]
    SWC
    SHELL
    1504.8
    [m]
    C
    SHELL
    1507.1
    [m]
    C
    SHELL
    1507.9
    [m]
    C
    SHELL
    1508.8
    [m]
    C
    SHELL
    1509.0
    [m]
    C
    SHELL
    1510.7
    [m]
    C
    SHELL
    1512.0
    [m]
    C
    SHELL
    1512.5
    [m]
    C
    SHELL
    1513.3
    [m]
    C
    SHELL
    1514.7
    [m]
    C
    SHELL
    1515.5
    [m]
    C
    SHELL
    1515.8
    [m]
    C
    SHELL
    1528.4
    [m]
    C
    SHELL
    1529.1
    [m]
    C
    SHELL
    1533.4
    [m]
    C
    SHELL
    1534.3
    [m]
    C
    SHELL
    1537.0
    [m]
    C
    SHELL
    1539.7
    [m]
    C
    SHELL
    1540.2
    [m]
    C
    SHELL
    1542.0
    [m]
    C
    SHELL
    1542.4
    [m]
    C
    SHELL
    1555.8
    [m]
    C
    SHELL
    1557.9
    [m]
    C
    SHELL
    1558.0
    [m]
    C
    SHELL
    1558.6
    [m]
    C
    SHELL
    1576.9
    [m]
    C
    SHELL
    1578.9
    [m]
    C
    SHELL
    1582.2
    [m]
    C
    SHELL
    1584.5
    [m]
    C
    SHELL
    1589.0
    [m]
    C
    SHELL
    1591.8
    [m]
    C
    SHELL
    1591.8
    [m]
    C
    SHELL
    1592.9
    [m]
    C
    SHELL
    1594.5
    [m]
    C
    SHELL
    1601.1
    [m]
    C
    SHELL
    1601.8
    [m]
    C
    SHELL
    1601.9
    [m]
    C
    SHELL
    1603.4
    [m]
    C
    SHELL
    1603.7
    [m]
    C
    SHELL
    1604.4
    [m]
    C
    SHELL
    1606.0
    [m]
    C
    SHELL
    1609.6
    [m]
    C
    SHELL
    1609.8
    [m]
    C
    SHELL
    1620.1
    [m]
    C
    SHELL
    1624.2
    [m]
    C
    SHELL
    1625.3
    [m]
    C
    SHELL
    1626.2
    [m]
    C
    SHELL
    1627.1
    [m]
    C
    SHELL
    1634.0
    [m]
    C
    SHELL
    1655.0
    [m]
    C
    SHELL
    1682.8
    [m]
    C
    SHELL
    1703.0
    [m]
    C
    SHELL
    1718.0
    [m]
    C
    SHELL
    1728.0
    [m]
    C
    SHELL
    1740.1
    [m]
    C
    SHELL
    1754.0
    [m]
    C
    SHELL

  • 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
    TEST1
    1576.00
    1579.00
    20.09.1981 - 00:00
    YES
    DST
    TEST2
    1518.00
    1536.00
    06.10.1981 - 00:00
    YES

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.29

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.60
    pdf
    0.54

  • 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
    1.20
    pdf
    33.29
    pdf
    1.55
    pdf
    6.83
    pdf
    4.01
    pdf
    1.15
    pdf
    1.86
    pdf
    1.48
    pdf
    1.34
    pdf
    1.48
    pdf
    3.19
    pdf
    1.08
    pdf
    3.19
    pdf
    1.00
    pdf
    0.25
    pdf
    0.15
    pdf
    0.96
    pdf
    0.15
    pdf
    1.09
    pdf
    0.65
    pdf
    1.28
    pdf
    0.70
    pdf
    2.54
    pdf
    0.16
    pdf
    0.20
    pdf
    0.20
    pdf
    0.21
    pdf
    0.21
    pdf
    0.21
    pdf
    4.44
    pdf
    0.43
    pdf
    0.51
    pdf
    1.03
    pdf
    0.91
    pdf
    0.92
    pdf
    0.61
    pdf
    1.79
    pdf
    0.35
    pdf
    3.29
    pdf
    13.65
    pdf
    16.00
    pdf
    8.12
    pdf
    1.20
    pdf
    0.24
    pdf
    0.26
    pdf
    0.18
    pdf
    0.38
    pdf
    6.86
    pdf
    0.10
    pdf
    0.75
    pdf
    10.32
    pdf
    1.54
    pdf
    4.82
    pdf
    2.13
    pdf
    0.49
    pdf
    0.21
    pdf
    0.44
    pdf
    1.42
    pdf
    0.28
    pdf
    0.71
    pdf
    1.43
    pdf
    0.31
    pdf
    2.67
    pdf
    0.45

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    1576
    1579
    7.9
    2.0
    1518
    1537
    50.8
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    2.0
    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
    144
    25000
    0.888
    0.605
    175
    2.0
    40
    1699000
    0.781
    0.602
    42475

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    BGT GR
    447
    814
    BGT GR
    447
    817
    BGT GR
    447
    817
    CBL VDL
    370
    802
    CBL VDL
    635
    1475
    CBL VDL
    850
    1715
    CST
    801
    1463
    DLL MSFL CAL
    1476
    1756
    FDC CNL GR CAL
    447
    819
    FDC CNL GR CAL
    801
    1471
    FDC CNL GR CAL
    1476
    1757
    HDT
    1476
    1758
    ISF BHC GR
    447
    817
    ISF BHC GR
    801
    1473
    ISF BHC GR
    1476
    1757
    LDT
    1476
    1757
    NGT
    1476
    1757
    RFT
    13
    0
    VELOCITY
    0
    0

  • 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
    448.0
    36
    456.0
    0.00
    LOT
    SURF.COND.
    20
    800.0
    26
    820.0
    0.00
    LOT
    INTERM.
    13 3/8
    1475.0
    17 1/2
    1485.0
    1.62
    LOT
    INTERM.
    9 5/8
    1752.0
    12 1/4
    1760.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    420
    0.00
    seawater
    820
    1.12
    50.0
    water based
    1485
    1.32
    50.0
    water based
    1532
    1.18
    52.0
    water based

  • 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
    0.15