Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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25.11.2024 - 01:30
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31/2-14

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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.
    31/2-14
    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.
    31/2-14
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    Line 8007-147
    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.
    411-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.
    60
    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,
    23.04.1984
    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.
    21.06.1984
    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.
    21.06.1986
    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.
    06.06.2006
    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.
    340.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    1725.0
    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).
    1725.0
    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.
    74
    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° 51' 26.52'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    3° 25' 37.68'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6747135.56
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    523206.43
    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.
    106

  • Wellbore history
    General
    Appraisal well 31/2-14 was drilled on the north-western margin of the Troll field. The main objectives of the well were to demonstrate the production potential for oil in the northern part of the Troll oil province, to evaluate the proposed template development scheme and to confirm the predicted extension of high energy progradation sands in the northern region.
    Operations and results
    Well 31/2-14 was spudded with the semi-submersible installation Borgny Dolphin on 23 April 1984 and drilled to TD at 1725 m in the Middle Jurassic Fensfjord Formation. The site survey before spud showed, as usual for the area, a seabed with numerous pockmarks (12 pockmarks/km3 on average). After setting the 13 3/8" casing shoe at 1498 m a leak in the kill-line was discovered, leading to repairs of the BOP and replacement of the marine riser. After 10 days lost time normal operations could resume. The well was drilled with seawater and hi-vis pills down to 814 m, with KCl/polymer mud from 814 m to 1513 m, and with chalk mud from 1513 m to TD.
    No sands were encountered above the Jurassic.The well encountered hydrocarbons in the Late Jurassic Sognefjord Formation. Top reservoir was penetrated at 1533 m (1508 m SS). The GOC was at 1566 m (1541 m SS) and the FWL was at 1592 m (1567 m SS). The oil-bearing interval consists of medium to low quality sands with a very clean layer (7m) some 3 m above the OWC. Below 1595 m (top Heather Formation) the sands are micaceous. The core measured permeability values range from 10 mD to 10 Darcy. In the gas bearing part of the cored interval no to weak fluorescence was recorded. In the oil zone (1561 - 1592 m) the fluorescence varied from weak to strong. Below 1594 m no fluorescence was recorded. Seven cores were cut from 1535 m to 1599 m in the Late Jurassic sequence. No samples were taken on wire line.
    The well was permanently abandoned on 21 June as a gas and oil appraisal.
    Testing
    The clean sand interval 1583.3 - 1590.3 m in the oil zone was perforated and completed with an internal gravel. A long duration production test was carried out in an attempt to obtain gas breakthrough. The well was beaned up to 1335 Sm3 oil/day and flowed for 9.5 days. Gas breakthrough did not occur. The oil was a 28.1 deg API gravity oil with a GOR of 60 Sm3/Sm3. Maximum temperature recorded during the test was 68.3 deg. C, which correspond to a temperature gradient of 53 deg C/km above the reservoir.

  • 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]
    490.00
    1725.00

  • 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
    1535.0
    1542.2
    [m ]
    2
    1544.5
    1553.8
    [m ]
    3
    1560.0
    1562.9
    [m ]
    4
    1564.0
    1570.0
    [m ]
    5
    1571.0
    1576.9
    [m ]
    6
    1580.0
    1586.3
    [m ]
    7
    1589.5
    1598.2
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    46.3
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 1535-1541m
    Core photo at depth: 1541-1542m
    Core photo at depth: 1544-1550m
    Core photo at depth: 1550-1553m
    Core photo at depth: 1560-1562m
    1535-1541m
    1541-1542m
    1544-1550m
    1550-1553m
    1560-1562m
    Core photo at depth: 1564-1570m
    Core photo at depth: 1570-1570m
    Core photo at depth: 1571-1576m
    Core photo at depth: 1580-1586m
    Core photo at depth: 1586-1586m
    1564-1570m
    1570-1570m
    1571-1576m
    1580-1586m
    1586-1586m
    Core photo at depth: 1589-1595m
    Core photo at depth: 1595-1598m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    1589-1595m
    1595-1598m

  • 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
    TEST-1
    1590.00
    1583.00
    OIL
    10.06.1984 - 00:00
    YES

  • Lithostratigraphy
    Lithostratigraphy
    Top depth [mMD RKB]
    Lithostrat. unit
    365
    799
    1326
    1326
    1375
    1421
    1526
    1530
    1532
    1532
    1533
    1595
    1685

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.23

  • 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
    8.20
    pdf
    2.69
    pdf
    0.39
    pdf
    1.27
    pdf
    1.27
    pdf
    0.39
    pdf
    2.69
    pdf
    0.16
    pdf
    3.33
    pdf
    0.62
    pdf
    0.09
    pdf
    0.06
    pdf
    0.05
    pdf
    3.08
    pdf
    0.52
    pdf
    0.10
    pdf
    0.06
    pdf
    0.07
    pdf
    2.00
    pdf
    1.02
    pdf
    0.91
    pdf
    0.96
    pdf
    1.13
    pdf
    1.27
    pdf
    1.54
    pdf
    0.89
    pdf
    1.54
    pdf
    0.53
    pdf
    0.89
    pdf
    0.53
    pdf
    2.69
    pdf
    2.00
    pdf
    1.02
    pdf
    0.91
    pdf
    2.69
    pdf
    0.16
    pdf
    1.27
    pdf
    0.05
    pdf
    3.33
    pdf
    0.62
    pdf
    0.09
    pdf
    0.06
    pdf
    3.08
    pdf
    0.52
    pdf
    0.10
    pdf
    0.06
    pdf
    0.07
    pdf
    0.96
    pdf
    1.13

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    BGT GR
    345
    515
    CBL VDL
    364
    1488
    CBL VDL
    900
    1690
    CET GR
    900
    1690
    CNL GR
    1530
    1580
    CST
    1510
    1602
    CST
    1604
    1713
    GR CCL
    1550
    1692
    ISF SONIC GR
    350
    814
    ISF SONIC GR
    814
    1506
    ISF SONIC GR
    1503
    1719
    LDL CNL GR
    464
    814
    LDL CNL GR
    814
    1513
    LDT CNL SGT
    1496
    1654
    MSFL DLL GR
    1496
    1714
    RFT
    1533
    1633
    SHDT GR
    1496
    1718

  • 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
    464.0
    36
    474.0
    0.00
    LOT
    SURF.COND.
    20
    799.0
    26
    810.0
    1.37
    LOT
    INTERM.
    13 3/8
    1498.0
    17 1/2
    1514.0
    1.52
    LOT
    INTERM.
    9 5/8
    1724.0
    12 1/4
    1725.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    500
    1.03
    WATER BASED
    550
    1.12
    WATER BASED
    600
    1.14
    WATER BASED
    650
    1.10
    WATER BASED
    750
    1.11
    WATER BASED
    800
    1.12
    WATER BASED
    850
    1.25
    WATER BASED
    900
    1.26
    WATER BASED
    1000
    1.27
    WATER BASED
    1200
    1.31
    WATER BASED
    1250
    1.30
    WATER BASED
    1515
    1.16
    WATER BASED
    1535
    1.13
    WATER BASED
    1545
    1.16
    WATER BASED
    1570
    1.17
    WATER BASED

  • 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
    0.14