Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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27.04.2024 - 01:34
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7220/7-3 S

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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.
    7220/7-3 S
    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.
    7220/7-3
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    WG08STR10-BIN:inline 1317 & xline 2603
    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.
    1509-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.
    66
    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,
    28.02.2014
    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.
    05.05.2014
    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.
    05.05.2016
    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.
    05.05.2016
    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.
    31.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    345.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2097.0
    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).
    2059.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    34.6
    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° 24' 8.73'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    20° 8' 2.69'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    8041437.29
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    673066.48
    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.
    7414

  • Wellbore history
    General
    Well 7220/7-3 S was drilled to test the Drivis prospect on the Bjørnøyrenna Fault Complex in the Barents Sea, about 15 kilometres southwest of the 7220/8-1 Johan Castberg discovery. The primary exploration target was to prove petroleum in reservoir rocks from the Middle and Early Jurassic Age (the Stø and Nordmela formations). Flat spots at these levels were believed to be gas-oil and oil-water contacts. The secondary exploration target was to prove petroleum in reservoir rocks from the Late Triassic Age (the Fruholmen formation).
    Operations and results
    Wildcat well 7220/7-3 S was spudded with the semi-submersible installation West Hercules on 28 February 2014 and drilled to TD at 2097 m (2059 m TVD) in the Late Triassic Fruholmen Formation. No shallow gas was observed even though a shallow gas warning Class 2 was given through the Tertiary Torsk Formation. TD of the 17 1/2" section was set shallower than planned due to stuck pipe. Otherwise, no significant problem was encountered in the operations. The well was drilled with seawater and sweeps down to 736 m and with KCl/GEM/Polymer mud from 736 m to TD.
    Top Stø Formation was encountered at 1448 m and top Nordmela Formation at 1525 m. There was a 68-metre gross gas column in the Stø Formation and an 86-metre gross oil column in the Stø and Nordmela formations. The GOC is at 1516 m and the OWC is at 1604 m. The reservoir quality in the Stø formation is very good. The reservoir quality in the Nordmela Formation is variable, but about half of the oil zone was encountered in sandstone with very good reservoir quality. Oil shows of variable quality are described from the OWC and down to 1766 in the Tubåen Formation. The Fruholmen Formation has poor reservoir properties, and is mostly water bearing, but petroleum was recovered in an MDT sample from 1952.2 m. In this petroleum, the gas and light oil components were less mature than in the oil in Nordmela, while the heavier fraction (C15+) was similar to the oil in Nordmela. There were also some oil shows in the interval 1907 to 1925 m in Nordmela.
    A total of 140.7 m core was recovered in two cores from the interval 1457 m to 1597.6 m in the Stø and Nordmela formations. The recovery was 100%. MDT fluid samples were taken at 1458 m (gas), 1545.5 m (oil), 1578 m (oil), 1609.5 m (water), and at 1952.2 m (oil).
    The well was permanently abandoned on 5 May 2014 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]
    715.00
    2096.00

  • 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
    1457.0
    1527.4
    [m ]
    2
    1527.4
    1597.6
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    140.6
    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
    740.0
    [m]
    DC
    ROBERTSO
    770.0
    [m]
    DC
    ROBERT
    800.0
    [m]
    DC
    ROBERT
    830.0
    [m]
    DC
    ROBERT
    865.0
    [m]
    DC
    ROBERT
    895.0
    [m]
    DC
    ROBERT
    920.0
    [m]
    DC
    ROBERT
    940.0
    [m]
    DC
    ROBERT
    960.0
    [m]
    DC
    ROBERT
    980.0
    [m]
    DC
    ROBERT
    1000.0
    [m]
    DC
    ROBERT
    1020.0
    [m]
    DC
    ROBERT
    1040.0
    [m]
    DC
    ROBERT
    1060.0
    [m]
    DC
    ROBERT
    1080.0
    [m]
    DC
    ROBERT
    1100.0
    [m]
    DC
    ROBERT
    1120.0
    [m]
    DC
    ROBERT
    1140.0
    [m]
    DC
    ROBERT
    1160.0
    [m]
    DC
    ROBERT
    1180.0
    [m]
    DC
    ROBERT
    1200.0
    [m]
    DC
    ROBERT
    1220.0
    [m]
    DC
    ROBERT
    1240.0
    [m]
    DC
    ROBERT
    1260.0
    [m]
    DC
    ROBERT
    1280.0
    [m]
    DC
    ROBERT
    1300.0
    [m]
    DC
    ROBERT
    1320.0
    [m]
    DC
    ROBERT
    1340.0
    [m]
    DC
    ROBERT
    1360.0
    [m]
    DC
    ROBERT
    1362.0
    [m]
    DC
    ROBERT
    1380.0
    [m]
    DC
    ROBERT
    1400.0
    [m]
    DC
    ROBERT
    1406.0
    [m]
    DC
    ROBERT
    1412.0
    [m]
    DC
    ROBERT
    1424.0
    [m]
    DC
    ROBERT
    1430.0
    [m]
    DC
    ROBERT
    1436.0
    [m]
    DC
    ROBERT
    1442.0
    [m]
    DC
    ROBERT
    1448.0
    [m]
    DC
    ROBERT
    1454.0
    [m]
    DC
    ROBERT
    1457.5
    [m]
    C
    ROBERT
    1463.3
    [m]
    C
    ROBERT
    1469.8
    [m]
    C
    ROBERT
    1474.1
    [m]
    C
    ROBERT
    1480.1
    [m]
    C
    ROBERT
    1486.4
    [m]
    C
    ROBERT
    1489.5
    [m]
    C
    ROBERT
    1496.8
    [m]
    C
    ROBERT
    1502.0
    [m]
    C
    ROBERT
    1508.6
    [m]
    C
    ROBERT
    1514.3
    [m]
    C
    ROBERT
    1520.5
    [m]
    C
    ROBERT
    1526.5
    [m]
    C
    ROBERT
    1530.6
    [m]
    C
    ROBERT
    1536.2
    [m]
    C
    ROBERT
    1542.3
    [m]
    C
    ROBERT
    1548.7
    [m]
    C
    ROBERT
    1551.8
    [m]
    C
    ROBERT
    1555.3
    [m]
    C
    ROBERT
    1562.4
    [m]
    C
    ROBERT
    1567.7
    [m]
    C
    ROBERT
    1574.4
    [m]
    C
    ROBERT
    1581.8
    [m]
    C
    ROBERT
    1586.4
    [m]
    C
    ROBERT
    1589.9
    [m]
    C
    ROBERT
    1595.7
    [m]
    C
    ROBERT
    1597.5
    [m]
    C
    ROBERT
    1604.0
    [m]
    DC
    ROBERT
    1610.0
    [m]
    DC
    ROBERT
    1616.0
    [m]
    DC
    ROBERT
    1622.0
    [m]
    DC
    ROBERT
    1628.0
    [m]
    DC
    ROBERT
    1634.0
    [m]
    DC
    ROBERT
    1640.0
    [m]
    DC
    ROBERT
    1646.0
    [m]
    DC
    ROBERT
    1652.0
    [m]
    DC
    ROBERT
    1658.0
    [m]
    DC
    ROBERT
    1664.0
    [m]
    DC
    ROBERT
    1670.0
    [m]
    DC
    ROBERT
    1679.0
    [m]
    DC
    ROBERT
    1685.0
    [m]
    DC
    ROBERT
    1691.0
    [m]
    DC
    ROBERT
    1697.0
    [m]
    DC
    ROBERT
    1706.0
    [m]
    DC
    ROBERT
    1712.0
    [m]
    DC
    ROBERT
    1718.0
    [m]
    DC
    ROBERT
    1724.0
    [m]
    DC
    ROBERT
    1730.0
    [m]
    DC
    ROBERT
    1736.0
    [m]
    DC
    ROBERT
    1742.0
    [m]
    DC
    ROBERT
    1751.0
    [m]
    DC
    ROBERT
    1757.0
    [m]
    DC
    ROBERT
    1763.0
    [m]
    DC
    ROBERT
    1769.0
    [m]
    DC
    ROBERT
    1775.0
    [m]
    DC
    ROBERT
    1781.0
    [m]
    DC
    ROBERT
    1787.0
    [m]
    DC
    ROBERT
    1793.0
    [m]
    DC
    ROBERT
    1799.0
    [m]
    DC
    ROBERT
    1814.0
    [m]
    DC
    ROBERT
    1829.0
    [m]
    DC
    ROBERT
    1844.0
    [m]
    DC
    ROBERT
    1859.0
    [m]
    DC
    ROBERT
    1874.0
    [m]
    DC
    ROBERT
    1889.0
    [m]
    DC
    ROBERT
    1904.0
    [m]
    DC
    ROBERT
    1919.0
    [m]
    DC
    ROBERT
    1934.0
    [m]
    DC
    ROBERT
    1949.0
    [m]
    DC
    ROBERT
    1967.0
    [m]
    DC
    ROBERT
    1979.0
    [m]
    DC
    ROBERT
    1994.0
    [m]
    DC
    ROBERT
    2009.0
    [m]
    DC
    ROBERT
    2024.0
    [m]
    DC
    ROBERT
    2039.0
    [m]
    DC
    ROBERT
    2054.0
    [m]
    DC
    ROBERT
    2069.0
    [m]
    DC
    ROBERT
    2084.0
    [m]
    DC
    ROBERT
    2096.0
    [m]
    DC
    ROBERT

  • 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
    1543.30
    0.00
    OIL
    23.09.2014 - 00:00
    YES
    MDT
    1952.20
    0.00
    OIL
    23.09.2014 - 00:00
    YES

  • Lithostratigraphy

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    ARCRES9 TELE
    428
    737
    CMR HRLA PEX ECS HNGS
    1359
    1800
    FMI PPC1B MSIP PPC2B GR
    1877
    1900
    MDT
    1458
    1952
    MDT
    1545
    1545
    MINIFRAC
    0
    0
    PD ARC TELE SON ADN
    737
    1362
    PD RAB6 DVDM6 TELE675 VSONIC6
    1362
    2097
    TELE
    376
    427
    USIT CBL
    894
    1355
    VSP
    744
    744

  • 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
    36
    425.1
    42
    428.0
    0.00
    INTERM.
    13 3/8
    708.7
    17 1/2
    736.0
    1.26
    FIT
    LINER
    9 5/8
    1359.0
    12 1/4
    1400.0
    1.65
    LOT
    OPEN HOLE
    2097.0
    8 1/2
    2097.0
    0.00

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    710
    1.06
    15.0
    Spud Mud
    730
    1.11
    11.0
    KCl/Polymer/GEM
    736
    1.06
    11.0
    KCl/Polymer/GEM
    736
    1.06
    9.0
    Spud Mud
    737
    1.14
    19.0
    KCl/Polymer/GEM
    838
    1.12
    18.0
    KCl/Polymer/GEM
    847
    1.12
    20.0
    KCl/Polymer/GEM
    1049
    1.23
    27.0
    KCl/Polymer/GEM
    1058
    1.13
    26.0
    KCl/Polymer/GEM
    1362
    1.12
    20.0
    KCl/Polymer/GEM
    1397
    1.20
    28.0
    KCl/Polymer/GEM
    1466
    1.23
    28.0
    KCl/Polymer/GEM
    2096
    1.23
    27.0
    KCl/Polymer/GEM