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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2/9-4

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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.
    2/9-4
    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.
    NORTH SEA
    Well name
    Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    2/9-4
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    inline 1137 & trace 1385
    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.
    ConocoPhillips Skandinavia 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.
    1177-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.
    107
    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,
    20.03.2008
    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.
    04.07.2008
    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.
    04.07.2010
    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.
    01.08.2010
    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.
    DRY
    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
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    45.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    70.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    5500.0
    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).
    5489.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    6.9
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    158
    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.
    EARLY PERMIAN
    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.
    ROTLIEGEND GP
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    56° 16' 28.89'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    3° 48' 45.95'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6237087.88
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    550332.01
    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.
    5801

  • Wellbore history
    General
    The 2/9-4 Trane well is located on the Piggvar Terrace in the Norwegian Sector of the Danish-Norwegian Basin in
    the North Sea. The target prospect was seen as a continuation of the recent Danish sector Hejre discovery structural trend and reservoir/trap system and the sole objective of the well was to explore the hydrocarbon potential of the Jurassic J62 Heno Formation (Gert Member Sandstone) prospect. The 2/9-4 well location was planned to be approximately 10 km from the Danish sector Hejre-2 well location. The Trane well was planned as a near-vertical HPHT well with a prognosed TD at 5512 m or when sufficient rat hole was drilled below the base of the Karl Volcanics to allow testing in the discovery case and full coverage logging in the wet case.
    Operations and results
    Wildcat well 2/9-4 was spudded with the jack-up installation Mærsk Galant on 20 March 2008 and drilled to TD at 5500 m in volcanic rocks within the Permian Rotliegend Group. An apparent influx into the wellbore was observed while drilling at 5056 m with 16.9ppg MW and required an increase in MW to 17.0 ppg to allow drilling to continue. The ECD immediately prior to this "influx" had been 17.2 ppg and the influx was thought to have been caused by gas expansion near surface after drilling into a gas pocket trapped beneath a thin dolomitic limestone stringer. A flow check at 5116 m due to high drilled gas levels in the mud showed the well was flowing at 14bbl/hr with a MW of 17.4ppg. The well required 17.7 ppg MW to return to a static condition. The Pore Pressure through this section was significantly higher than the pre-drill estimate and appeared to indicate that the Trane structure represented an isolated block with a different structural and pressure history to the adjacent Hejre structure. Losses of 26 bbl/hr were noted at 5475 m and were cured after pumping and soaking 2 LCM pills. Drilling continued to TD without further incident. The well was drilled with sea water and hi-vis pills down to 203 m, with spud mud from 203 m to 1007 m, with Glydril mud from 1007 m to 2495 m, with Paratherm oil based mud from 2495 m to 2715.5 m, and with WARP oil based mud from 2715.5 m to TD.
    No reservoir quality sands were developed at any level below Miocene level. The Gert Member Sandstone objective was absent. The oil-based muds used as the drilling fluids for the entire well below the 20" shoe at 1002.1 m, made
    shows identification difficult. No shows that could be distinguished from the OBM were observed.
    Wire line logging runs gave a bottom hole maximum temperature of 156 deg C with Horner plot corrections suggesting a maximum static down hole temperature at TD of 158 deg C.
    No cores were cut and no wire line fluid samples were taken.
    The well was permanently abandoned on 4 July 2008 as a dry 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]
    200.00
    5500.00

  • Lithostratigraphy

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    DSL ORIT XMAC HDIL CN ZDL
    115
    5493
    GR VSP
    800
    5485
    MWD LWD - DGR
    1007
    2510
    MWD LWD - EWR PWD
    2500
    4715
    MWD LWD - GR EWR PWD
    4715
    5500
    MWD LWD - PWD
    115
    1007

  • 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
    195.0
    36
    203.0
    0.00
    LOT
    SURF.COND.
    20
    1002.0
    26
    1007.0
    1.74
    LOT
    INTERM.
    13 5/8
    2499.0
    17 1/2
    2510.0
    1.89
    LOT
    INTERM.
    9 7/8
    4710.0
    12 1/4
    4715.0
    2.19
    LOT
    OPEN HOLE
    5500.0
    8 1/2
    5500.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    300
    1.16
    4.0
    water based
    500
    1.14
    7.0
    water based
    596
    1.13
    6.0
    water based
    895
    1.18
    5.0
    water based
    1005
    1.14
    6.0
    water based
    1007
    1.60
    32.0
    water based
    1007
    1.13
    6.0
    water based
    1225
    1.60
    31.0
    water based
    1742
    1.60
    32.0
    water based
    2252
    1.60
    38.0
    water based
    2510
    1.62
    34.0
    water based
    2922
    1.65
    40.0
    oil based
    3252
    1.65
    38.0
    oil based
    3540
    1.65
    35.0
    oil based
    3650
    1.65
    37.0
    oil based
    3730
    1.65
    33.0
    oil based
    3819
    1.65
    35.0
    oil based
    3941
    1.65
    37.0
    oil based
    3994
    1.65
    35.0
    oil based
    4045
    1.74
    39.0
    oil based
    4076
    1.74
    38.0
    oil based
    4139
    1.74
    35.0
    oil based
    4187
    1.74
    39.0
    oil based
    4223
    1.74
    40.0
    oil based
    4346
    1.74
    38.0
    oil based
    4470
    1.74
    44.0
    oil based
    4568
    1.74
    46.0
    oil based
    4635
    1.74
    43.0
    oil based
    4685
    1.74
    42.0
    oil based
    4716
    2.00
    47.0
    oil based
    4716
    2.00
    45.0
    oil based
    4716
    1.74
    43.0
    oil based
    4716
    1.74
    42.0
    oil based
    4750
    2.00
    43.0
    oil based
    4811
    2.00
    42.0
    oil based
    4878
    2.00
    39.0
    oil based
    4946
    2.00
    41.0
    oil based
    4988
    0.20
    45.0
    oil based
    5026
    2.00
    48.0
    oil based
    5034
    2.00
    45.0
    oil based
    5056
    2.03
    45.0
    oil based
    5117
    2.10
    52.0
    oil based
    5184
    2.12
    61.0
    oil based
    5223
    2.12
    61.0
    oil based
    5297
    2.12
    58.0
    oil based
    5343
    2.12
    63.0
    oil based
    5384
    2.12
    66.0
    oil based
    5500
    2.12
    58.0
    oil based