Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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22.12.2024 - 01:25
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7220/5-1

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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.
    7220/5-1
    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).
    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
    Press release
    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
    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.
    7220/5-1
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    3D survey WG08STR10-inline 1514 & crossline 3698
    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.
    Statoil Petroleum AS
    Drill permit
    The drilling permit number together with the version of the drilling permit as stated in the drilling permit granted by the Norwegian Offshore Directorate.
    1393-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.
    58
    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,
    27.01.2012
    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.
    24.03.2012
    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.
    24.03.2014
    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.
    24.03.2014
    Purpose - planned
    Pre-drill purpose of the wellbore. Legal values for exploration wellbores: WILDCAT, APPRAISAL, WILDCAT-CCS, APPRAISAL-CCS. Example of legal values for development wellbores: OBSERVATION, PRODUCTION, INJECTION.
    APPRAISAL
    Reentry
    Status whether the wellbore has been re-entered (YES) or not (NO). Re-entered wellbores are not included in the count when wellbores are presented in statistical overviews.
    NO
    Content
    For exploration wellbores, status of discovery.

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

    For development wellbores, type of produced/injected fluid.
    Legal values:
    WATER, CUTTINGS, NOT AVAILABLE, OIL, GAS/CONDENSATE, OIL/GAS, CO2, GAS, WATER/GAS, NOT APPLICABLE.
    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.
    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.
    STØ FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    40.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    388.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    1740.0
    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).
    1740.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    4.46
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    52
    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.
    LATE 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.
    FRUHOLMEN FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    72° 31' 0.67'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    20° 20' 29.15'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    8054765.92
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    678905.94
    UTM zone
    Universal Transverse Mercator zone. Examples of legal values: 31, 32, 33, 34.
    33
    NPDID wellbore
    Norwegian Offshore Directorate's unique id for the wellbore.
    6775

  • Wellbore history
    General
    Well 7220/5-1 was drilled to appraise the 7220/8-1 Skrugard Discovery in the Bjarmøyrenna Fault complex west of the Loppa High in the Barents Sea. The Skrugard structure is divided into three segments by erosion features, making saddle points that separate the three gas-oil contacts. The discovery well 7220/8-1 is located in the southern segment, while the appraisal well 7220/5-1 is located in the middle segment. The appraisal well is located approximately 3 km to the North of the Skrugard discovery well. The main objectives of well 7220/5-1were to prove gas and oil volumes in the Skrugard middle segment and communication between the middle and southern segments. This implied proving the exact depths of the gas-oil-contact and oil-water-contact and collecting fluid sampling from the reservoir. Another objective was to perform an extended leak-off test or similar in the cap seal and in the reservoir and to core and analyse the cap seal and reservoir.
    Operations and results
    Prior to the main bore a 9 5/8" pilot hole (7220/5-U-1) was drilled down to 875 m MD RT to check for shallow gas. This was approximately the setting depth of the 9 5/8" casing. No shallow gas was observed. Appraisal well 7220/5-1 was spudded with the semi-submersible installation Transocean Barents on 27 January 2012 and drilled to TD at 1740 m in the Late Triassic Fruholmen Formation. No significant problem was encountered in the operations. The well was drilled with seawater and hi-vis pills down to 898 m and with KCl/Polymer/Glycol mud from 898 m to TD.
    The well penetrated Tertiary and Cretaceous Claystones and Sandstones, as well as Late Jurassic Claystones above the Reservoir. Top reservoir, Stø Formation sandstone, was encountered at 1337 m. In the Reservoir, the well penetrated Sandstones of Jurassic age within the Stø, Nordmela and Tubåen Formations, and Triassic age sandstones within the Fruholmen Formation. A 28 m thick gas column and a 47 m thick oil column were proven in the primary target of the Stø Formation. Results from the well indicate that two flat-spots seen on seismic represent the gas-oil contact (GOC) at 1365 m and the oil-water contact (OWC) at 1412 m. Oil shows continued down to 1419 m. No oil shows were recorded below this depth or above top Stø Formation.
    Eight cores were cut in the well. The first was cut from 1175 m to 1183 m in shales of the Kolmule Formation with 86% recovery. This core was preserved in oil. The other 7 cores were cut from 1322 m to 1624 m with very good recovery. They comprise the Fuglen Formation shales, the Fuglen/Stø boundary, the Stø Formation including the contacts, the Nordmela Formation, and the upper 46 m of the Tubåen Formation. MDT fluid samples were taken at 1351.8 m (gas), 1381 m (HC), 1404 m (oil), 1428.1 m (water, and 1611 m (water).
    The well was permanently abandoned on 24 March as an oil and gas appraisal well.
    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]
    900.00
    1740.00

  • 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
    2
    1339.0
    1349.0
    [m ]
    3
    1349.0
    1402.2
    [m ]
    4
    1402.0
    1455.5
    [m ]
    5
    1455.0
    1489.8
    [m ]
    6
    1491.0
    1544.3
    [m ]
    7
    1544.0
    1569.0
    [m ]
    8
    1570.0
    1623.2
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    282.9
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    900.0
    [m]
    DC
    FUGRO
    910.0
    [m]
    DC
    FUGRO
    920.0
    [m]
    DC
    FUGRO
    930.0
    [m]
    DC
    FUGRO
    940.0
    [m]
    DC
    FUGRO
    950.0
    [m]
    DC
    FUGRO
    960.0
    [m]
    DC
    FUGRO
    970.0
    [m]
    DC
    FUGRO
    980.0
    [m]
    DC
    FUGRO
    990.0
    [m]
    DC
    FUGRO
    1000.0
    [m]
    DC
    FUGRO
    1010.0
    [m]
    DC
    FUGRO
    1020.0
    [m]
    DC
    FUGRO
    1030.0
    [m]
    DC
    FUGRO
    1040.0
    [m]
    DC
    FUGRO
    1050.0
    [m]
    DC
    FUGRO
    1060.0
    [m]
    DC
    FUGRO
    1080.0
    [m]
    DC
    FUGRO
    1100.0
    [m]
    DC
    FUGRO
    1120.0
    [m]
    DC
    FUGRO
    1140.0
    [m]
    DC
    FUGRO
    1160.0
    [m]
    DC
    FUGRO
    1166.0
    [m]
    DC
    FUGRO
    1172.0
    [m]
    DC
    FUGRO
    1175.0
    [m]
    C
    FUGRO
    1178.0
    [m]
    C
    FUGRO
    1178.0
    [m]
    DC
    FUGRO
    1181.0
    [m]
    C
    FUGRO
    1187.9
    [m]
    SWC
    FUGRO
    1192.7
    [m]
    SWC
    FUGRO
    1195.3
    [m]
    SWC
    FUGRO
    1200.5
    [m]
    SWC
    FUGRO
    1208.0
    [m]
    SWC
    FUGRO
    1215.0
    [m]
    SWC
    FUGRO
    1222.5
    [m]
    SWC
    FUGRO
    1226.5
    [m]
    SWC
    FUGRO
    1232.1
    [m]
    SWC
    FUGRO
    1234.5
    [m]
    SWC
    FUGRO
    1236.0
    [m]
    SWC
    FUGRO
    1237.0
    [m]
    SWC
    FUGRO
    1238.8
    [m]
    SWC
    FUGRO
    1239.8
    [m]
    SWC
    FUGRO
    1241.1
    [m]
    SWC
    FUGRO
    1243.2
    [m]
    SWC
    FUGRO
    1246.0
    [m]
    SWC
    FUGRO
    1248.0
    [m]
    SWC
    FUGRO
    1248.6
    [m]
    SWC
    FUGRO
    1250.6
    [m]
    SWC
    FUGRO
    1252.2
    [m]
    SWC
    FUGRO
    1253.0
    [m]
    SWC
    FUGRO
    1256.1
    [m]
    SWC
    FUGRO
    1258.5
    [m]
    SWC
    FUGRO
    1259.2
    [m]
    SWC
    FUGRO
    1260.4
    [m]
    SWC
    FUGRO
    1262.2
    [m]
    SWC
    FUGRO
    1263.3
    [m]
    SWC
    FUGRO
    1265.4
    [m]
    SWC
    FUGRO
    1269.6
    [m]
    SWC
    FUGRO
    1272.3
    [m]
    SWC
    FUGRO
    1276.6
    [m]
    SWC
    FUGRO
    1277.2
    [m]
    SWC
    FUGRO
    1280.0
    [m]
    SWC
    FUGRO
    1282.3
    [m]
    SWC
    FUGRO
    1287.6
    [m]
    SWC
    FUGRO
    1293.0
    [m]
    SWC
    FUGRO
    1300.0
    [m]
    SWC
    FUGRO
    1304.0
    [m]
    DC
    FUGRO
    1307.0
    [m]
    SWC
    FUGRO
    1308.9
    [m]
    SWC
    FUGRO
    1310.5
    [m]
    SWC
    FUGRO
    1313.0
    [m]
    DC
    FUGRO
    1316.0
    [m]
    DC
    FUGRO
    1319.0
    [m]
    DC
    FUGRO
    1322.0
    [m]
    C
    FUGRO
    1325.0
    [m]
    C
    FUGRO
    1328.0
    [m]
    C
    FUGRO
    1331.0
    [m]
    C
    FUGRO
    1334.0
    [m]
    C
    FUGRO
    1337.0
    [m]
    C
    FUGRO
    1339.1
    [m]
    C
    FUGRO
    1339.5
    [m]
    C
    FUGRO
    1342.9
    [m]
    C
    FUGRO
    1345.9
    [m]
    C
    FUGRO
    1348.7
    [m]
    C
    FUGRO
    1350.9
    [m]
    C
    FUGRO
    1353.8
    [m]
    C
    FUGRO
    1356.9
    [m]
    C
    FUGRO
    1358.7
    [m]
    C
    FUGRO
    1361.9
    [m]
    C
    FUGRO
    1364.9
    [m]
    C
    FUGRO
    1367.1
    [m]
    C
    FUGRO
    1370.4
    [m]
    C
    FUGRO
    1373.2
    [m]
    C
    FUGRO
    1376.2
    [m]
    C
    FUGRO
    1379.9
    [m]
    C
    FUGRO
    1380.2
    [m]
    C
    FUGRO
    1384.5
    [m]
    C
    FUGRO
    1393.0
    [m]
    C
    FUGRO
    1396.5
    [m]
    C
    FUGRO
    1401.0
    [m]
    C
    FUGRO
    1407.8
    [m]
    C
    FUGRO
    1411.5
    [m]
    C
    FUGRO
    1415.4
    [m]
    C
    FUGRO
    1417.7
    [m]
    C
    FUGRO
    1420.7
    [m]
    C
    FUGRO
    1423.8
    [m]
    C
    FUGRO
    1425.5
    [m]
    C
    FUGRO
    1429.6
    [m]
    C
    FUGRO
    1432.5
    [m]
    C
    FUGRO
    1434.9
    [m]
    C
    FUGRO
    1436.8
    [m]
    C
    FUGRO
    1440.2
    [m]
    C
    FUGRO
    1440.8
    [m]
    C
    FUGRO
    1443.7
    [m]
    C
    FUGRO
    1444.2
    [m]
    C
    FUGRO
    1447.6
    [m]
    C
    FUGRO
    1450.8
    [m]
    C
    FUGRO
    1453.2
    [m]
    C
    FUGRO
    1455.4
    [m]
    C
    FUGRO
    1457.8
    [m]
    C
    FUGRO
    1460.6
    [m]
    C
    FUGRO
    1463.5
    [m]
    C
    FUGRO
    1466.5
    [m]
    C
    FUGRO
    1470.0
    [m]
    C
    FUGRO
    1472.4
    [m]
    C
    FUGRO
    1475.7
    [m]
    C
    FUGRO
    1478.9
    [m]
    C
    FUGRO
    1481.7
    [m]
    C
    FUGRO
    1484.6
    [m]
    C
    FUGRO
    1487.7
    [m]
    C
    FUGRO
    1491.1
    [m]
    C
    FUGRO
    1494.0
    [m]
    C
    FUGRO
    1497.3
    [m]
    C
    FUGRO
    1500.1
    [m]
    C
    FUGRO
    1506.7
    [m]
    C
    FUGRO
    1512.7
    [m]
    C
    FUGRO
    1518.5
    [m]
    C
    FUGRO
    1523.5
    [m]
    C
    FUGRO
    1529.5
    [m]
    C
    FUGRO
    1536.0
    [m]
    C
    FUGRO
    1542.0
    [m]
    C
    FUGRO
    1545.8
    [m]
    C
    FUGRO
    1550.7
    [m]
    C
    FUGRO
    1556.7
    [m]
    C
    FUGRO
    1562.4
    [m]
    C
    FUGRO
    1568.5
    [m]
    C
    FUGRO
    1573.8
    [m]
    C
    FUGRO
    1576.5
    [m]
    C
    FUGRO
    1580.4
    [m]
    C
    FUGRO
    1585.0
    [m]
    C
    FUGRO
    1590.6
    [m]
    C
    FUGRO
    1596.6
    [m]
    C
    FUGRO
    1602.6
    [m]
    C
    FUGRO
    1608.8
    [m]
    C
    FUGRO
    1617.8
    [m]
    C
    FUGRO
    1622.8
    [m]
    C
    FUGRO
    1628.0
    [m]
    DC
    FUGRO
    1634.0
    [m]
    DC
    FUGRO
    1640.0
    [m]
    DC
    FUGRO
    1646.0
    [m]
    DC
    FUGRO
    1652.0
    [m]
    DC
    FUGRO
    1658.0
    [m]
    DC
    FUGRO
    1664.0
    [m]
    DC
    FUGRO
    1670.0
    [m]
    DC
    FUGRO
    1676.0
    [m]
    DC
    FUGRO
    1682.0
    [m]
    DC
    FUGRO
    1688.0
    [m]
    DC
    FUGRO
    1694.0
    [m]
    DC
    FUGRO
    1700.0
    [m]
    DC
    FUGRO
    1706.0
    [m]
    DC
    FUGRO
    1712.0
    [m]
    DC
    FUGRO
    1718.0
    [m]
    DC
    FUGRO
    1724.0
    [m]
    DC
    FUGRO
    1730.0
    [m]
    DC
    FUGRO
    1736.0
    [m]
    DC
    FUGRO
    1740.0
    [m]
    DC
    FUGRO

  • 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
    MDT
    1404.00
    0.00
    OIL
    YES
    MDT
    1404.10
    0.00
    OIL
    YES
    MDT
    0.00
    1381.00
    OIL
    YES

  • Lithostratigraphy

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    FMI GR
    872
    1158
    MWD - ARCVIS6 TELE
    1285
    1735
    MWD - ARCVISION9 TELE
    490
    898
    MWD - GVR ARCVIS6 TELE
    1166
    1315
    MWD - PERI15 TELE VADN6
    898
    1166
    MWD - TELE
    428
    493
    ZAIT IS MSIP PEX
    872
    1160
    ZAIT IS MSIP PEX
    1050
    1739

  • 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
    490.0
    36
    493.0
    0.00
    LOT
    PILOT HOLE
    878.0
    9 7/8
    878.0
    0.00
    LOT
    SURF.COND.
    13 3/8
    893.0
    17 1/2
    898.0
    1.24
    LOT
    INTERM.
    9 5/8
    1164.0
    12 1/4
    1166.0
    1.58
    LOT
    LINER
    7
    1503.0
    8 1/2
    1740.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    760
    1.17
    11.0
    Low Sulphate/KCl/Polymer/Glycol
    900
    1.12
    8.0
    KCl/Polymer/Glycol
    1092
    1.13
    14.0
    KCl/Polymer/Glycol
    1166
    1.17
    15.0
    KCl/Polymer/Glycol
    1166
    1.16
    17.0
    KCl/Polymer/Glycol
    1177
    1.25
    13.0
    Low Sulphate/KCl/Polymer/Glycol
    1272
    1.17
    11.0
    Low Sulphate/KCl/Polymer/Glycol
    1361
    1.25
    13.0
    Low Sulphate/KCl/Polymer/Glycol
    1500
    1.17
    11.0
    Low Sulphate/KCl/Polymer/Glycol
    1545
    1.25
    14.0
    Low Sulphate/KCl/Polymer/Glycol
    1740
    1.17
    11.0
    Low Sulphate/KCl/Polymer/Glycol
    1740
    1.25
    15.0
    Low Sulphate/KCl/Polymer/Glycol

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