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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9/4-5

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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.
    9/4-5
    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.
    9/4-5
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    NSR04-42232 2D Surveu- shot point 2900
    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.
    ExxonMobil Exploration and Production Norway 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.
    1097-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.
    206
    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,
    08.01.2006
    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.
    01.08.2006
    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.
    01.08.2008
    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.
    15.08.2008
    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.
    44.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    77.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    5881.0
    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).
    5874.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    8.5
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    150
    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.
    CARBONIFEROUS
    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.
    NO FORMAL NAME
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    57° 40' 38.91'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    4° 16' 8.37'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6393656.30
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    575683.43
    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.
    5134

  • Wellbore history
    Well is located in the Egersund Basin south-west of the Yme field in the North Sea. The main target for the well was a faulted four way anticlinal structure (rotated fault block) with Late Permian Rotliegendes sandstones at a prognosed depth of 5134 m. About 400 m of Rotliegendes sandstone was expected. The objective was to test the hydrocarbon potential in this structure. Dry gas was expected. The key risks were the Palaeozoic source, reservoir adequacy, and top seal. The well should TD just below the base Rotliegendes (Saalian Unconformity) to obtain full stratigraphic and lithological control for the Rotliegendes.
    Operations and results
    Well 9/4-5 was spudded with the jack-up installation Mærsk Gallant on 6 January 2006 and drilled to TD at 5881 m (5874 m TVD RKB), 44 m into volcanic tuffs below the base of the Permian Rotliegendes Group. Rotliegendes drilling was very slow, about 1-2 m/hour. The well encountered a five meters thick halite bed at 5224 m, the base of the Zechstein in the 9 7/8" hole. On several bit trips in and out of the hole, the halite was seen slowly moving into the well, giving some problems coming into the well and pulling out of hole, most of the times this interval needed to be reamed. When drilling at 5503 m with 13 ppg mud weight, a salt water kick occurred. ECD at this time was 13.7 ppg. The mud weight was gradually increased to 15.5 ppg to stop the salt water influx into the well. The well was drilled with seawater and hi-vis sweeps down to 605 m, with Glydril mud containing 3% glycol from 605 m to 2534 m, and with Paratherm oil based mud containing alkanes mainly in the range C12-C18 from 2534 m to TD.
    The well encountered Top Rotliegendes at 5278.5 m (5272 m TVD RKB), 138 m deep to prognosis. The total Rotliegendes was 559 m thick, consisting of about 500 m of tight sandstones and conglomerates. A few meters of the sandstone beds had porosity up to about 8%. These porous beds were water wet. The lowest part of the Rotliegendes consists of 60 m with brown to red clay stones, with a sharp log contact to varicoloured tuffs. The well was dry. Apart from some elevated gas in the Tau formation only background gas was encountered and frequent fluorescence observed in deeper parts of the well, in the reservoir section, was due to the base oil in the mud. Post-well organic geochemical analyses confirmed this picture. Vitrinite reflection analyses (%Ro) proved an immature well down to ca 2600 m where %Ro exceeded 0.5.
    Two cores were cut in different reservoir facies in the Rotliegendes section, the first core showing grey tight sandstones and the second core, deeper down in the reservoir, showing red tight conglomerates and red sandstones with 8% porosity. Extensive wire line logging was done at TD, including Earth Imager, MREX (Magnetic Resonance), XMAC (Sonic), HDIL (Resistivity) and Check shots. Formation pressures and samples were attempted with the RCI Probe and RCI Straddle Packer tools. The fluid sampling failed. A number of long-time BHT's measured on wire line tools repeatedly gave maximum temperatures in the range 145 - 148 deg C. Horner correction gave a static temperature at final TD in the range149 - 152 deg C.
    The well was permanently abandoned on 1 August 2006 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]
    607.00
    5881.00

  • 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
    5294.7
    5296.9
    [m ]
    2
    5535.2
    5551.6
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    18.6
    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
    625.0
    [m]
    DC
    FUGRO
    661.0
    [m]
    DC
    FUGRO
    690.0
    [m]
    DC
    FUGRO
    771.0
    [m]
    DC
    FUGRO
    789.0
    [m]
    DC
    FUGRO
    807.0
    [m]
    DC
    FUGRO
    826.0
    [m]
    DC
    FUGRO
    853.0
    [m]
    DC
    FUGRO
    881.0
    [m]
    DC
    FUGRO
    900.0
    [m]
    DC
    FUGRO
    1045.0
    [m]
    DC
    FUGRO
    1100.0
    [m]
    DC
    FUGRO
    1128.0
    [m]
    DC
    FUGRO
    1183.0
    [m]
    DC
    FUGRO
    1247.0
    [m]
    DC
    FUGRO
    1265.0
    [m]
    DC
    FUGRO
    1311.0
    [m]
    DC
    FUGRO
    1366.0
    [m]
    DC
    FUGRO
    1402.0
    [m]
    DC
    FUGRO
    1630.0
    [m]
    DC
    FUGRO
    1841.0
    [m]
    DC
    FUGRO
    1987.0
    [m]
    DC
    FUGRO
    2024.0
    [m]
    DC
    FUGRO
    2115.0
    [m]
    DC
    FUGRO
    2252.0
    [m]
    DC
    FUGRO
    2353.0
    [m]
    DC
    FUGRO
    2399.0
    [m]
    DC
    FUGRO
    2463.0
    [m]
    DC
    FUGRO
    2534.0
    [m]
    DC
    FUGRO
    2600.0
    [m]
    DC
    FUGRO
    2618.0
    [m]
    DC
    FUGRO
    2636.0
    [m]
    DC
    FUGRO
    2657.0
    [m]
    DC
    FUGRO
    2691.0
    [m]
    DC
    FUGRO
    2706.0
    [m]
    DC
    FUGRO
    2795.0
    [m]
    DC
    FUGRO
    2804.0
    [m]
    DC
    FUGRO
    2831.0
    [m]
    DC
    FUGRO
    2859.0
    [m]
    DC
    FUGRO
    2950.0
    [m]
    DC
    FUGRO
    3179.0
    [m]
    DC
    FUGRO
    3334.0
    [m]
    DC
    FUGRO
    3453.0
    [m]
    DC
    FUGRO
    3545.0
    [m]
    DC
    FUGRO
    3718.0
    [m]
    DC
    FUGRO
    3837.0
    [m]
    DC
    FUGRO
    4121.0
    [m]
    DC
    FUGRO
    4349.0
    [m]
    DC
    FUGRO
    4560.0
    [m]
    DC
    FUGRO
    4633.0
    [m]
    DC
    FUGRO
    4752.0
    [m]
    DC
    FUGRO
    4862.0
    [m]
    DC
    FUGRO
    4944.0
    [m]
    DC
    FUGRO
    5008.0
    [m]
    DC
    FUGRO
    5099.0
    [m]
    DC
    FUGRO
    5135.0
    [m]
    DC
    FUGRO
    5190.0
    [m]
    DC
    FUGRO
    5222.0
    [m]
    DC
    FUGRO
    5227.0
    [m]
    DC
    FUGRO
    5234.0
    [m]
    DC
    FUGRO
    5261.0
    [m]
    DC
    FUGRO
    5270.0
    [m]
    DC
    FUGRO
    5276.0
    [m]
    DC
    FUGRO
    5295.0
    [m]
    DC
    FUGRO
    5296.4
    [m]
    C
    FUGRO
    5296.7
    [m]
    C
    FUGRO
    5312.0
    [m]
    DC
    FUGRO
    5318.0
    [m]
    DC
    FUGRO
    5334.0
    [m]
    DC
    FUGRO
    5346.0
    [m]
    DC
    FUGRO
    5455.0
    [m]
    DC
    FUGRO
    5502.0
    [m]
    DC
    FUGRO
    5523.0
    [m]
    DC
    FUGRO
    5776.0
    [m]
    DC
    FUGRO
    5779.0
    [m]
    DC
    FUGRO
    5782.0
    [m]
    DC
    FUGRO
    5785.0
    [m]
    DC
    FUGRO
    5788.0
    [m]
    DC
    FUGRO
    5791.0
    [m]
    DC
    FUGRO
    5794.0
    [m]
    DC
    FUGRO
    5797.0
    [m]
    DC
    FUGRO
    5800.0
    [m]
    DC
    FUGRO
    5803.0
    [m]
    DC
    FUGRO
    5806.0
    [m]
    DC
    FUGRO
    5809.0
    [m]
    DC
    FUGRO
    5813.0
    [m]
    DC
    FUGRO
    5816.0
    [m]
    DC
    FUGRO
    5831.0
    [m]
    DC
    FUGRO
    5846.0
    [m]
    DC
    FUGRO
    5867.0
    [m]
    DC
    FUGRO
    5881.0
    [m]
    DC
    FUGRO

  • Lithostratigraphy

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    txt
    0.00
    txt
    0.16
    pdf
    3.66

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    LWD - GR MPR
    608
    2534
    LWD - GR MPR APX CLSS
    5112
    5235
    LWD - GR MPR CCN ORD APX
    2534
    4043
    LWD - GR MPR CCN ORD APX CLSS
    4043
    5112
    LWD - GR OTK
    5445
    5655
    LWD - GR OTK CCN ORD
    5297
    5445
    LWD - GR OTK CCN ORD CLSS
    5655
    5881
    LWD - GR OTK CLSS
    5235
    5295
    MREX HDIL GR
    5275
    5687
    MREX HDIL GR
    5600
    5775
    RCI GR
    5292
    5554
    RCI GR
    5292
    5616
    RCI GR
    5331
    5332
    RCI GR
    5568
    5569
    VSP GR
    2547
    5882
    XMAC EI GR
    5160
    5882

  • 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
    207.0
    42
    213.0
    0.00
    LOT
    SURF.COND.
    20
    599.0
    26
    605.0
    1.57
    LOT
    INTERM.
    13 5/8
    2526.0
    17
    2534.0
    1.88
    LOT
    INTERM.
    9 7/8
    5209.0
    12 1/4
    5234.0
    2.20
    LOT
    OPEN HOLE
    5295.0
    9 7/8
    5295.0
    0.00
    LOT
    OPEN HOLE
    5881.0
    8 1/2
    5881.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    213
    1.04
    DUMMY
    605
    1.08
    DUMMY
    1402
    1.21
    80.0
    DUMMY
    1980
    1.23
    31.0
    DUMMY
    2534
    0.00
    DUMMY
    3168
    1.37
    38.0
    DUMMY
    4002
    1.37
    35.0
    DUMMY
    4354
    1.37
    34.0
    DUMMY
    4686
    0.00
    DUMMY
    4945
    1.37
    34.0
    DUMMY
    5746
    1.86
    47.0
    DUMMY
    5881
    1.86
    48.0
    DUMMY
    5881
    0.00
    DUMMY