Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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05.11.2024 - 01:27
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31/2-9

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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.
    31/2-9
    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.
    31/2-9
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    79403 SP 435
    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.
    344-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.
    34
    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,
    29.08.1982
    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.
    01.10.1982
    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.
    01.10.1984
    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
    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.
    339.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    1770.0
    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).
    1770.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    2.25
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    46
    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° 52' 54.34'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    3° 28' 3.43'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6749867.74
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    525386.67
    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.
    88

  • Wellbore history
    General
    Well 31/2-9 was drilled northeast of the well 31/2-7 in the Troll West oil province in the Northern North Sea. The main objectives were to establish the extent of a previously proven thick oil column province in the Troll Field and to complete the well near the OWC in order to follow the development of water coning.
    Operations and results
    Well 31/2-9 was spudded with the semi-submersible installation Borgny Dolphin on 29 August 1982 and drilled to TD at 1770 m in the Late Jurassic Fensfjord Formation. Some problems were encountered with the well head after running the 20" casing (2.5 days lost), and with the BOP after running the 13 3/8" casing (3.5 days lost). The well was drilled with spud mud down to 460 m, with seawater and gel from 460 m to 816 m, with KCl/polymer mud from 816 m to 1509 m, and with seawater/Drispac mud from 1509 m to TD.
    Well 31/2-9 encountered a hydrocarbon bearing column of 34.5 m in the Late Jurassic Sognefjord Formation. The reservoir was gas bearing from 1549 -1570 m (21 m gas column) and oil bearing down to 1583.5 m (13.5 m oil column). This was a thinner oil column than expected. The gas reservoir consisted of very fine to medium grained bioturbated sandstones with a high mica content. The sandstones were very silty and well sorted. Around 1570 m a change in lithology to medium/ coarse grained sandstones with low mica content and less bioturbation was seen. In the lower part of the oil reservoir the mica content was slightly more than in the upper part and the sandstones were siltier. Below the OWC shows (moderate to very weak direct fluorescence) were observed on cores throughout the cored section down to 1628 m.
    Five fiberglass sleeved cores were taken in the 12 1/4" section from 1554 to 1628 m. Four RFT runs were made and 5 samples were obtained: at 1573 m (29 deg API oil), 1571 m (oil), 1565 m (gas), and two samples at 1575 m (oil)
    The well was permanently abandoned on 1 October 1982 as a gas and oil 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]
    470.00
    1768.00

  • 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
    1554.0
    1563.0
    [m ]
    2
    1563.0
    1571.3
    [m ]
    3
    1573.0
    1591.6
    [m ]
    4
    1591.6
    1607.8
    [m ]
    5
    1610.0
    1627.7
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    69.8
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 1554-1559m
    Core photo at depth: 1559-1563m
    Core photo at depth: 1563-1568m
    Core photo at depth: 1568-1571m
    Core photo at depth: 1573-1578m
    1554-1559m
    1559-1563m
    1563-1568m
    1568-1571m
    1573-1578m
    Core photo at depth: 1578-1583m
    Core photo at depth: 1583-1589m
    Core photo at depth: 1589-1591m
    Core photo at depth: 1591-1597m
    Core photo at depth: 1597-1602m
    1578-1583m
    1583-1589m
    1589-1591m
    1591-1597m
    1597-1602m
    Core photo at depth: 1602-1607m
    Core photo at depth: 1610-1615m
    Core photo at depth: 1615-1620m
    Core photo at depth: 1620-1626m
    Core photo at depth: 1628-1627m
    1602-1607m
    1610-1615m
    1615-1620m
    1620-1626m
    1628-1627m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1279.0
    [m]
    DC
    RRI
    1288.0
    [m]
    DC
    RRI
    1297.0
    [m]
    DC
    RRI
    1306.0
    [m]
    DC
    RRI
    1315.0
    [m]
    DC
    RRI
    1324.0
    [m]
    DC
    RRI
    1333.0
    [m]
    DC
    RRI
    1342.0
    [m]
    DC
    RRI
    1351.0
    [m]
    DC
    RRI
    1357.0
    [m]
    DC
    RRI
    1369.0
    [m]
    DC
    RRI
    1378.0
    [m]
    DC
    RRI
    1387.0
    [m]
    DC
    RRI
    1396.0
    [m]
    DC
    RRI
    1405.0
    [m]
    DC
    RRI
    1414.0
    [m]
    DC
    RRI
    1423.0
    [m]
    DC
    RRI
    1432.0
    [m]
    DC
    RRI
    1441.0
    [m]
    DC
    RRI
    1450.0
    [m]
    DC
    RRI
    1459.0
    [m]
    DC
    RRI
    1468.0
    [m]
    DC
    RRI
    1477.0
    [m]
    DC
    RRI
    1486.0
    [m]
    DC
    RRI
    1538.0
    [m]
    SWC
    GEOCH
    1539.0
    [m]
    SWC
    GEOCH
    1540.0
    [m]
    C
    GEOCH
    1540.0
    [m]
    SWC
    GEOCH
    1541.0
    [m]
    SWC
    GEOCH
    1542.0
    [m]
    C
    GEOCH
    1543.0
    [m]
    C
    GEOCH
    1544.0
    [m]
    C
    GEOCH
    1545.0
    [m]
    C
    GEOCH
    1546.0
    [m]
    C
    GEOCH
    1547.0
    [m]
    C
    GEOCH
    1548.0
    [m]
    SWC
    GEOCH
    1549.0
    [m]
    SWC
    GEOCH
    1552.0
    [m]
    SWC
    GEOCH
    1554.0
    [m]
    SWC
    GEOCH
    1555.0
    [m]
    C
    GEOCH
    1559.0
    [m]
    C
    GEOCH
    1560.0
    [m]
    C
    GEOCH
    1564.0
    [m]
    C
    GEOCH
    1570.0
    [m]
    C
    GEOCH
    1574.0
    [m]
    C
    GEOCH
    1578.0
    [m]
    C
    GEOCH
    1583.0
    [m]
    C
    GEOCH
    1592.0
    [m]
    C
    GEOCH
    1602.0
    [m]
    C
    GEOCH
    1614.0
    [m]
    C
    GEOCH
    1622.0
    [m]
    C
    GEOCH
    1624.0
    [m]
    C
    GEOCH
    1625.0
    [m]
    C
    GEOCH
    1628.0
    [m]
    C
    GEOCH
    1633.0
    [m]
    C
    GEOCH
    1643.0
    [m]
    SWC
    GEOCH
    1656.0
    [m]
    C
    GEOCH
    1667.0
    [m]
    SWC
    GEOCH
    1678.0
    [m]
    C
    GEOCH
    1688.0
    [m]
    SWC
    GEOCH
    1698.0
    [m]
    C
    GEOCH
    1707.0
    [m]
    SWC
    GEOCH
    1713.0
    [m]
    C
    GEOCH
    1725.0
    [m]
    C
    GEOCH
    1730.0
    [m]
    SWC
    GEOCH
    1735.0
    [m]
    SWC
    GEOCH
    1747.0
    [m]
    SWC
    GEOCH
    1756.0
    [m]
    SWC
    GEOCH

  • Lithostratigraphy

  • 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
    8.07
    pdf
    2.03
    pdf
    0.71
    pdf
    1.31
    pdf
    0.38
    pdf
    0.10
    pdf
    0.02
    pdf
    2.62
    pdf
    3.40
    pdf
    0.24
    pdf
    0.37
    pdf
    1.68
    pdf
    0.77
    pdf
    10.09
    pdf
    3.31
    pdf
    3.03
    pdf
    1.37
    pdf
    1.40
    pdf
    0.82

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL VDL
    520
    1500
    CST
    816
    1496
    CST
    1498
    1770
    DLL MSFL
    1498
    1767
    FDC CNL GR CAL
    450
    814
    HDT
    1498
    1770
    ISF BHC GR
    350
    812
    ISF BHC GR
    808
    1406
    ISF BHC GR
    1406
    1501
    ISF BHC GR
    1498
    1769
    LDT CNL GR CAL
    803
    1502
    LDT CNL GR CAL
    1498
    1770
    RFT
    1550
    1752
    WST
    776
    1769

  • 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
    450.0
    36
    460.0
    0.00
    LOT
    SURF.COND.
    20
    808.0
    26
    816.0
    1.47
    LOT
    INTERM.
    13 3/8
    1498.0
    17 1/2
    1509.0
    1.54
    LOT
    OPEN HOLE
    1770.0
    12 1/4
    1770.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    480
    1.05
    waterbased
    780
    1.12
    waterbased
    990
    1.28
    waterbased
    1290
    1.31
    waterbased
    1750
    1.18
    waterbased

  • 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