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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31/2-7

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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.
    31/2-7
    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
    Multilateral
    Indicator telling if the parent well is multilateral, meaning it has more than one branch radiating from the main borehole. Example of legal values: YES, NO. See also Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    NO
    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.
    31/2-7
    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.
    326-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.
    54
    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,
    22.04.1982
    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.
    14.06.1982
    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.
    14.06.1984
    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.
    19.12.2007
    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
    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.
    338.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    1660.0
    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).
    1660.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    1
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    71
    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 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.
    HEATHER FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    60° 51' 25.93'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    3° 27' 9.21'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6747126.56
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    524587.90
    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.
    70

  • Wellbore history
    General
    Well 31/2-7 was drilled in the Troll West oil province in the Northern North Sea. The primary objective was to appraise the oil accumulation in the area west of well 31/2-4 in the Troll Field.
    Operations and results
    Well 31/2-7 was spudded with the semi-submersible installation Borgny Dolphin on 22 April 1982 and drilled to TD at 1660 m in the Late Jurassic Heather Formation. No significant problems were encountered during operations. Tight spots were encountered in the 17 1/2" section. The well was drilled with seawater and hi-vis pills down to 455, with seawater/gel/CMC/Drispac from 455 m to 825 m, with KCl/polymer mud from 825 m to 1517 m, and with KCl/polymer/gel/lingo mud from 1517 m to TD.
    The well penetrated 11 m f Late Jurassic Draupne shale at 1535 m before entering the Sognefjord Formation reservoir sands at 1546 m. The Heather Formation was encountered at 1601 m. The Sognefjord Formation was hydrocarbon bearing with a 20.5 m gas column from 1545.5 - 1566 m and a 27.5 m oil column from 1566 to 1593.5 m. The gas reservoir consisted of alternating micaceous, bioturbated fine to medium grained sandstones and cross laminated, massive fine to coarse grained sandstones. The upper part of the oil reservoir (down to 1586 m) was of the same quality as the gas reservoir. Below 1586 m the sandstones were very fine to medium grained with high mica content. Weak shows (fluorescence and cut) were recorded on cores down to 1635 m.
    Six fibreglass sleeve cores were taken from 1547.0 m to 1635.0 m in the 8 1/2" section. Thus 88 m of core were cut of which 72.25 m (82%) was recovered. In order to verify the higher than expected GOC several unsuccessful (due to probe plugging) attempts were made to obtain RFT fluid samples at around 1570 m. Eventually one of the RFT chambers was filled at 1568 m. After a few more attempts the other chamber was filled at 1566.5 m. At surface the contents of both chambers were checked and found to be 29 API oil. This proved a 27.5 m oil column in the well and thus the existence of oil above 1547 m SS (1572 m), which had been interpreted as the GOC in all previous wells.
    The well was permanently abandoned on 14 June 1982 as an oil and gas appraisal.
    Testing
    The well was gravel packed and acidized before testing. A production test was carried out over the external gravel packed interval 1584 - 1590.5 m. The objectives were to investigate inflow performance and sand control, obtain representative fluid samples for PVT analyses, and to evaluate well coning performance. At maximum rate in the 92 hour long main flow the well flowed 1113 Sm3 oil/day on a 180/64" choke. The GOR was between 53 and 45 Sm3/Sm3, the oil density was 0.89 g/cm3 (27.5 deg API), and the gas gravity was 0.640. Maximum down-hole temperature recorded was 67.8 deg C.

  • 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]
    470.00
    1660.00

  • 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
    1547.0
    1556.5
    [m ]
    3
    1562.0
    1577.8
    [m ]
    4
    1587.5
    1597.0
    [m ]
    5
    1597.0
    1615.8
    [m ]
    6
    1616.0
    1634.7
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    72.3
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 1547-1553m
    Core photo at depth: 1553-1556m
    Core photo at depth: 1562-1568m
    Core photo at depth: 1568-1574m
    Core photo at depth: 1574-1577m
    1547-1553m
    1553-1556m
    1562-1568m
    1568-1574m
    1574-1577m
    Core photo at depth: 1587-1593m
    Core photo at depth: 1593-1597m
    Core photo at depth: 1597-1603m
    Core photo at depth: 1603-1609m
    Core photo at depth: 1609-1615m
    1587-1593m
    1593-1597m
    1597-1603m
    1603-1609m
    1609-1615m
    Core photo at depth: 1615-1616m
    Core photo at depth: 1616-1622m
    Core photo at depth: 1622-1628m
    Core photo at depth: 1628-1634m
    Core photo at depth: 1634-1635m
    1615-1616m
    1616-1622m
    1622-1628m
    1628-1634m
    1634-1635m

  • 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
    DST1
    1584.00
    1590.00
    06.06.1982 - 00:00
    YES

  • 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
    449.0
    36
    455.0
    0.00
    LOT
    SURF.COND.
    20
    812.0
    26
    825.0
    1.54
    LOT
    INTERM.
    13 3/8
    1495.0
    17 1/2
    1517.0
    1.59
    LOT
    INTERM.
    9 5/8
    1652.0
    12 1/4
    1660.0
    0.00
    LOT

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    1584
    1590
    71.0
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    68
    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
    1113
    0.887
    45

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    BGT GR
    1518
    1593
    BGT GR
    1522
    1592
    BGT GR
    1529
    1593
    CBL VDL GR CCL
    606
    1660
    CST
    812
    1510
    CST
    1498
    1770
    DLL MSFL GR
    1498
    1656
    FDC CNL GR CAL
    440
    824
    FDC CNL GR CAL
    812
    1510
    FDC CNL GR CAL
    1495
    1660
    HDT
    1495
    1660
    ISF BHC GR
    363
    822
    ISF BHC GR
    812
    1510
    ISF BHC GR
    1495
    1659
    LDT NGT CAL
    1495
    1660
    RFT
    0
    0
    VELOCITY
    776
    1650
    WST
    776
    1650

  • Lithostratigraphy
    Lithostratigraphy
    Top depth [mMD RKB]
    Lithostrat. unit
    363
    776
    1304
    1304
    1366
    1406
    1524
    1531
    1535
    1535
    1546
    1601

  • 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
    9.78
    pdf
    0.34
    pdf
    0.38
    pdf
    1.78
    pdf
    1.09
    pdf
    0.37
    pdf
    0.34
    pdf
    1.78
    pdf
    2.16
    pdf
    1.47
    pdf
    2.30
    pdf
    1.42
    pdf
    2.50
    pdf
    0.61
    pdf
    0.71
    pdf
    0.93
    pdf
    1.51
    pdf
    2.56
    pdf
    1.36
    pdf
    13.38
    pdf
    0.59
    pdf
    3.31

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    465
    1.07
    50.0
    waterbased
    600
    1.09
    50.0
    waterbased
    800
    1.10
    50.0
    waterbased
    800
    1.10
    48.0
    waterbased
    950
    1.31
    47.0
    waterbased
    1150
    1.31
    47.0
    waterbased
    1650
    1.19
    54.0
    waterbased

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1537.5
    [m]
    SWC
    SHELL
    1541.0
    [m]
    SWC
    SHELL
    1542.5
    [m]
    SWC
    SHELL
    1548.0
    [m]
    C
    SHELL
    1548.5
    [m]
    C
    SHELL
    1549.5
    [m]
    C
    SHELL
    1550.0
    [m]
    C
    SHELL
    1552.0
    [m]
    C
    SHELL
    1554.0
    [m]
    C
    SHELL
    1555.0
    [m]
    C
    SHELL
    1555.6
    [m]
    C
    SHELL
    1556.6
    [m]
    C
    SHELL
    1562.2
    [m]
    C
    SHELL
    1570.5
    [m]
    C
    SHELL
    1590.5
    [m]
    C
    SHELL
    1591.1
    [m]
    C
    SHELL
    1592.3
    [m]
    C
    SHELL
    1592.4
    [m]
    C
    SHELL
    1592.6
    [m]
    C
    SHELL
    1592.8
    [m]
    C
    SHELL
    1592.9
    [m]
    C
    SHELL
    1593.0
    [m]
    C
    SHELL
    1593.5
    [m]
    C
    SHELL
    1593.6
    [m]
    C
    SHELL
    1594.2
    [m]
    C
    SHELL
    1596.1
    [m]
    C
    SHELL
    1596.8
    [m]
    C
    SHELL
    1598.0
    [m]
    C
    SHELL
    1600.0
    [m]
    C
    SHELL
    1600.9
    [m]
    C
    SHELL
    1603.0
    [m]
    C
    SHELL
    1605.0
    [m]
    C
    SHELL
    1607.0
    [m]
    C
    SHELL
    1608.5
    [m]
    C
    SHELL
    1609.5
    [m]
    C
    SHELL
    1610.4
    [m]
    C
    SHELL
    1610.7
    [m]
    C
    SHELL
    1616.0
    [m]
    C
    SHELL
    1617.5
    [m]
    C
    SHELL
    1617.5
    [m]
    C
    SHELL
    1617.6
    [m]
    C
    SHELL
    1617.6
    [m]
    C
    SHELL
    1618.9
    [m]
    C
    SHELL
    1621.7
    [m]
    C
    SHELL
    1621.8
    [m]
    C
    SHELL
    1621.9
    [m]
    C
    SHELL
    1621.9
    [m]
    C
    SHELL
    1625.7
    [m]
    C
    SHELL
    1633.8
    [m]
    C
    SHELL
    1634.7
    [m]
    C
    SHELL
    1644.0
    [m]
    SWC
    SHELL
    1654.0
    [m]
    SWC
    SHELL
    1658.0
    [m]
    SWC
    SHELL