Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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28.04.2024 - 01:35
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7220/8-1

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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.
    7220/8-1
    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
    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.
    7220/8-1
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    3D survey WG08 -inline 1530 & crossline 3470
    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.
    1327-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.
    65
    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,
    27.02.2011
    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.
    02.05.2011
    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.
    02.05.2013
    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.
    02.05.2013
    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
    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.
    YES
    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
    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.
    EARLY 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.
    NORDMELA FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    23.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    374.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2222.0
    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).
    2221.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    3.2
    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.
    SNADD FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    72° 29' 28.92'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    20° 20' 2.25'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    8051910.71
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    678908.52
    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.
    6484

  • Wellbore history
    General
    Well 7220/8-1 was drilled just west of the Polheim Sub-platform and Loppa High in the Barents Sea. The main objective was to prove an economical volume of hydrocarbons and to establish hydrocarbon contacts in the Stø and Nordmela formations in the Skrugard Prospect. The targeted Skrugard fault block is one of several rotated fault blocks in the licence and a part of the Bjørnøyrenna Fault Complex.
    Operations and results
    A shallow 8 1/2" pre-spud well (7220/8-U-1) was drilled and logged to 955 m to check for shallow gas due to seismic anomalies around the well location. No shallow gas was encountered. After that wildcat well 7220/8-1 was spudded with the semi-submersible installation Polar Pioneer on 27 February 2011 and drilled to TD at 2222 m in the Late Triassic Snadd Formation. Drilling operations proceeded without significant problems but upon intermediate MDT logging the cable broke and about 10 days were lost fishing. The well was drilled with spud mud and hi-vis pills down to 850 m and with KCl/Polymer/Glycol from 850 m to TD.
    The well penetrated Tertiary and Cretaceous Claystones and Sandstones and upper Jurassic Claystones above the reservoir. In the reservoir the well penetrated Sandstones of Jurassic age, within the Stø, Nordmela and Tubåen Formations, and of Triassic age within the Fruholmen and Snadd Formations. The primary target reservoir was penetrated with top Stø Formation at 1276 m, and top Nordmela Formation at 1354 m. These Formations contained a 37 m thick gas column (GOC at 1312 m) and an 83 m thick oil column (OWC at 1395 m). Results from the well indicate that flat spots seen on the geo-seismic section represent the gas-oil-contact (GOC) and the oil-water-contact (OWC). The Snadd Formation was penetrated at 2122 m TVD, which was 35 m shallower than the prognosis.
    Very good hydrocarbon shows were seen when drilling the reservoir in the Stø and Nordmela Formations. No shows were observed below 1400 m in the core chips and cuttings.
    A total of five cores were cut in the Stø and Nordmela Formations, in the interval 1292.5 - 1405.5 m (97.8% recovery). Schlumberger MDT single probe was used for all samples. Oil samples were acquired at 1320.6 m, 1336.8 m, and at 1380.5 m in the Stø and Nordmela Formations. Due to the broken cable incident no water or gas samples were acquired.
    The well was permanently abandoned on 2 May 2011 as an oil and gas discovery.
    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]
    850.00
    2222.00

  • 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
    1292.5
    1296.5
    [m ]
    2
    1297.5
    1324.2
    [m ]
    3
    1324.5
    1351.4
    [m ]
    4
    1351.5
    1377.9
    [m ]
    5
    1378.5
    1405.0
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    110.5
    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
    850.0
    [m]
    DC
    STATOIL
    860.0
    [unknown]
    DC
    STATOIL
    870.0
    [unknown]
    DC
    STATOIL
    880.0
    [unknown]
    DC
    STATOIL
    890.0
    [unknown]
    DC
    STATOIL
    900.0
    [unknown]
    DC
    STATOIL
    910.0
    [unknown]
    DC
    STATOIL
    920.0
    [unknown]
    DC
    STATOIL
    930.0
    [unknown]
    DC
    STATOIL
    940.0
    [unknown]
    DC
    STATOIL
    950.0
    [unknown]
    DC
    STATOIL
    960.0
    [unknown]
    DC
    STATOIL
    970.0
    [unknown]
    DC
    STATOIL
    980.0
    [unknown]
    DC
    STATOIL
    990.0
    [unknown]
    DC
    STATOIL
    1000.0
    [unknown]
    DC
    STATOIL
    1010.0
    [unknown]
    DC
    STATOIL
    1020.0
    [unknown]
    DC
    STATOIL
    1030.0
    [unknown]
    DC
    STATOIL
    1040.0
    [unknown]
    DC
    STATOIL
    1050.0
    [unknown]
    DC
    STATOIL
    1060.0
    [unknown]
    DC
    STATOIL
    1080.0
    [unknown]
    DC
    STATOIL
    1090.0
    [unknown]
    DC
    STATOIL
    1100.0
    [unknown]
    DC
    STATOIL
    1110.0
    [unknown]
    DC
    STATOIL
    1120.0
    [unknown]
    DC
    STATOIL
    1130.0
    [unknown]
    DC
    STATOIL
    1140.0
    [unknown]
    DC
    STATOIL
    1150.0
    [unknown]
    DC
    STATOIL
    1160.0
    [unknown]
    DC
    STATOIL
    1170.0
    [unknown]
    DC
    STATOIL
    1180.0
    [unknown]
    DC
    STATOIL
    1190.0
    [unknown]
    DC
    STATOIL
    1200.0
    [unknown]
    DC
    STATOIL
    1203.0
    [unknown]
    DC
    STATOIL
    1209.0
    [unknown]
    DC
    STATOIL
    1215.0
    [unknown]
    DC
    STATOIL
    1221.0
    [unknown]
    DC
    STATOIL
    1227.0
    [unknown]
    DC
    STATOIL
    1233.0
    [unknown]
    DC
    STATOIL
    1239.0
    [unknown]
    DC
    STATOIL
    1245.0
    [unknown]
    DC
    STATOIL
    1252.0
    [unknown]
    DC
    STATOIL
    1258.0
    [unknown]
    DC
    STATOIL
    1261.0
    [unknown]
    DC
    STATOIL
    1270.0
    [unknown]
    DC
    STATOIL
    1276.0
    [unknown]
    DC
    STATOIL
    1279.0
    [unknown]
    DC
    STATOIL
    1285.0
    [unknown]
    DC
    STATOIL
    1288.0
    [unknown]
    DC
    STATOIL
    1291.0
    [unknown]
    DC
    STATOIL
    1291.0
    [unknown]
    DC
    STATOIL
    1292.5
    [unknown]
    C
    STATOIL
    1296.5
    [unknown]
    C
    STATOIL
    1302.0
    [unknown]
    C
    STATOIL
    1307.0
    [unknown]
    C
    STATOIL
    1313.0
    [unknown]
    C
    STATOIL
    1316.0
    [unknown]
    C
    STATOIL
    1324.2
    [unknown]
    C
    STATOIL
    1330.0
    [unknown]
    C
    STATOIL
    1335.8
    [unknown]
    C
    STATOIL
    1340.0
    [unknown]
    C
    STATOIL
    1343.8
    [unknown]
    C
    STATOIL
    1350.0
    [unknown]
    C
    STATOIL
    1351.3
    [unknown]
    C
    STATOIL
    1354.0
    [unknown]
    C
    STATOIL
    1357.0
    [unknown]
    C
    STATOIL
    1358.0
    [unknown]
    C
    STATOIL
    1364.0
    [unknown]
    C
    STATOIL
    1367.0
    [unknown]
    C
    STATOIL
    1371.9
    [unknown]
    C
    STATOIL
    1377.0
    [unknown]
    C
    STATOIL
    1377.9
    [unknown]
    C
    STATOIL
    1382.4
    [unknown]
    C
    STATOIL
    1387.5
    [unknown]
    C
    STATOIL
    1390.0
    [unknown]
    C
    STATOIL
    1396.5
    [unknown]
    C
    STATOIL
    1400.0
    [unknown]
    C
    STATOIL
    1405.5
    [unknown]
    C
    STATOIL
    1414.0
    [unknown]
    C
    STATOIL
    1420.0
    [unknown]
    DC
    STATOIL
    1426.0
    [unknown]
    DC
    STATOIL
    1432.0
    [unknown]
    DC
    STATOIL
    1438.0
    [unknown]
    DC
    STATOIL
    1444.0
    [unknown]
    DC
    STATOIL
    1450.0
    [unknown]
    DC
    STATOIL
    1456.0
    [unknown]
    DC
    STATOIL
    1462.0
    [unknown]
    DC
    STATOIL
    1471.0
    [unknown]
    DC
    STATOIL
    1480.0
    [unknown]
    DC
    STATOIL
    1489.0
    [unknown]
    DC
    STATOIL
    1495.0
    [unknown]
    DC
    STATOIL
    1504.0
    [unknown]
    DC
    STATOIL
    1510.0
    [unknown]
    DC
    STATOIL
    1519.0
    [unknown]
    DC
    STATOIL
    1525.0
    [unknown]
    DC
    STATOIL
    1531.0
    [unknown]
    DC
    STATOIL
    1537.0
    [unknown]
    DC
    STATOIL
    1543.0
    [unknown]
    DC
    STATOIL
    1549.0
    [unknown]
    DC
    STATOIL
    1555.0
    [unknown]
    DC
    STATOIL
    1561.0
    [unknown]
    DC
    STATOIL
    1567.0
    [unknown]
    DC
    STATOIL
    1573.0
    [unknown]
    DC
    STATOIL
    1579.0
    [unknown]
    DC
    STATOIL
    1585.0
    [unknown]
    DC
    STATOIL
    1591.0
    [unknown]
    DC
    STATOIL
    1597.0
    [unknown]
    DC
    STATOIL
    1603.0
    [unknown]
    DC
    STATOIL
    1609.0
    [unknown]
    DC
    STATOIL
    1615.0
    [unknown]
    DC
    STATOIL
    1621.0
    [unknown]
    DC
    STATOIL
    1630.0
    [unknown]
    DC
    STATOIL
    1636.0
    [unknown]
    DC
    STATOIL
    1642.0
    [unknown]
    DC
    STATOIL
    1642.0
    [unknown]
    DC
    STATOIL
    1648.0
    [unknown]
    DC
    STATOIL
    1654.0
    [unknown]
    DC
    STATOIL
    1660.0
    [unknown]
    DC
    STATOIL
    1666.0
    [unknown]
    DC
    STATOIL
    1672.0
    [unknown]
    DC
    STATOIL
    1678.0
    [unknown]
    DC
    STATOIL
    1684.0
    [unknown]
    DC
    STATOIL
    1690.0
    [unknown]
    DC
    STATOIL
    1699.0
    [unknown]
    DC
    STATOIL
    1705.0
    [unknown]
    DC
    STATOIL
    1711.0
    [unknown]
    DC
    STATOIL
    1720.0
    [unknown]
    DC
    STATOIL
    1726.0
    [unknown]
    DC
    STATOIL
    1738.0
    [unknown]
    DC
    STATOIL
    1744.0
    [unknown]
    DC
    STATOIL
    1750.0
    [unknown]
    DC
    STATOIL
    1756.0
    [unknown]
    DC
    STATOIL
    1768.0
    [unknown]
    DC
    STATOIL
    1780.0
    [unknown]
    DC
    STATOIL
    1789.0
    [unknown]
    DC
    STATOIL
    1798.0
    [unknown]
    DC
    STATOIL
    1807.0
    [unknown]
    DC
    STATOIL
    1816.0
    [unknown]
    DC
    STATOIL
    1828.0
    [unknown]
    DC
    STATOIL
    1840.0
    [unknown]
    DC
    STATOIL
    1849.0
    [unknown]
    DC
    STATOIL
    1858.0
    [unknown]
    DC
    STATOIL
    1867.0
    [unknown]
    DC
    STATOIL
    1876.0
    [unknown]
    DC
    STATOIL
    1888.0
    [unknown]
    DC
    STATOIL
    1897.0
    [unknown]
    DC
    STATOIL
    1906.0
    [unknown]
    DC
    STATOIL
    1915.0
    [unknown]
    DC
    STATOIL
    1921.0
    [unknown]
    DC
    STATOIL
    1930.0
    [unknown]
    DC
    STATOIL
    1939.0
    [unknown]
    DC
    STATOIL
    1948.0
    [unknown]
    DC
    STATOIL
    1954.0
    [unknown]
    DC
    STATOIL
    1963.0
    [unknown]
    DC
    STATOIL
    1972.0
    [unknown]
    DC
    STATOIL
    1978.0
    [unknown]
    DC
    STATOIL
    1990.0
    [unknown]
    DC
    STATOIL
    1999.0
    [unknown]
    DC
    STATOIL
    2008.0
    [unknown]
    DC
    STATOIL
    2017.0
    [unknown]
    DC
    STATOIL
    2026.0
    [unknown]
    DC
    STATOIL
    2032.0
    [unknown]
    DC
    STATOIL
    2041.0
    [unknown]
    DC
    STATOIL
    2050.0
    [unknown]
    DC
    STATOIL
    2059.0
    [unknown]
    DC
    STATOIL
    2065.0
    [unknown]
    DC
    STATOIL
    2071.0
    [unknown]
    DC
    STATOIL
    2080.0
    [unknown]
    DC
    STATOIL
    2086.0
    [unknown]
    DC
    STATOIL
    2095.0
    [unknown]
    DC
    STATOIL
    2104.0
    [unknown]
    DC
    STATOIL
    2116.0
    [unknown]
    DC
    STATOIL
    2125.0
    [unknown]
    DC
    STATOIL
    2134.0
    [unknown]
    DC
    STATOIL
    2146.0
    [unknown]
    DC
    STATOIL
    2155.0
    [unknown]
    DC
    STATOIL
    2161.0
    [unknown]
    DC
    STATOIL
    2170.0
    [unknown]
    DC
    STATOIL
    2179.0
    [unknown]
    DC
    STATOIL
    2188.0
    [unknown]
    DC
    STATOIL
    2197.0
    [unknown]
    DC
    STATOIL
    2203.0
    [unknown]
    DC
    STATOIL
    2212.0
    [unknown]
    DC
    STATOIL
    2218.0
    [unknown]
    DC
    STATOIL
    2222.0
    [unknown]
    DC
    STATOIL

  • 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
    1380.50
    0.00
    OIL
    13.04.2011 - 00:00
    YES

  • Lithostratigraphy

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.14
    pdf
    1.73

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL CAL
    397
    865
    CMR ECS
    839
    1436
    FMI MSIP
    1200
    1436
    MDT
    1251
    1472
    MDT
    1278
    1300
    MDT
    1278
    1472
    MSIP ZAIT CA CBL
    1
    100
    MSIP ZAIT CA CBL
    680
    1245
    MWD - ARCVRES8 TELESCOPE
    852
    942
    MWD - PERI15 TELE VADN6
    942
    1472
    MWD - TELESCOPE
    397
    852
    PEX HNGS GR
    1225
    1436
    PEX HRLA
    1250
    2122
    USIT
    675
    1255
    VSP
    500
    2122
    VSP TOOL STRING
    1000
    1255
    XPT
    1424
    2151
    ZAIT MSIP
    1250
    2122

  • 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
    470.0
    36
    474.0
    0.00
    LOT
    SURF.COND.
    9 5/8
    838.0
    12 1/4
    850.0
    1.25
    LOT
    LINER
    7
    1251.0
    8 1/2
    1252.0
    0.00
    LOT
    OPEN HOLE
    2222.0
    6
    2222.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    397
    1.60
    19.0
    Kill Fluid- SW/Bentonite
    397
    1.05
    15.0
    Spud Mud
    471
    1.05
    14.0
    Spud Mud
    472
    1.60
    19.0
    Kill Fluid- SW/Bentonite
    474
    1.05
    12.0
    Spud Mud
    474
    1.60
    19.0
    Kill Fluid- SW/Bentonite
    850
    1.05
    12.0
    Spud Mud
    850
    1.20
    20.0
    KCl/Polymer/Glycol
    850
    1.25
    21.0
    KCl/Polymer/Glycol
    850
    1.05
    12.0
    Spud Mud
    872
    1.15
    12.0
    KCl/Polymer/Glycol
    1035
    1.12
    13.0
    KCl/Polymer/Glycol
    1252
    1.12
    13.0
    KCl/Polymer/Glycol
    1252
    1.15
    12.0
    KCl/Polymer/Glycol
    1379
    1.24
    15.0
    KCl/Polymer/Glycol
    1472
    1.21
    12.0
    KCl/Polymer/Glycol
    1472
    1.23
    13.0
    KCl/Polymer/Glycol
    1472
    1.24
    12.0
    KCl/Polymer/Glycol
    2222
    1.21
    14.0
    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
    0.28