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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6305/4-2 S

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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.
    6305/4-2 S
    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
    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.
    NORWEGIAN 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.
    6305/4-2
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    inline 4119 & crossline 5608 on OLSH 0801
    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.
    1322-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.
    100
    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,
    04.11.2010
    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.
    11.02.2011
    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.
    11.02.2013
    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.
    11.02.2013
    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.
    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.
    36.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    1086.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2985.0
    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).
    2905.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    25.4
    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 CRETACEOUS
    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.
    NISE FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    63° 38' 14.9'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    5° 17' 54.12'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7058837.63
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    613859.59
    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.
    6441

  • Wellbore history
    General
    The Ormen Lange appraisal well 6305/4-2 S was drilled within the DHI limits in the NW of the Ormen Lange field in the Norwegian Sea. The main objectives were to appraise the fluid content and reservoir quality of the Egga Reservoir Unit (Egga informal Formation), and to investigate the degree of pressure communication between the planned northern area C-template and the existing central area A-and B-templates
    Operations and results
    Appraisal well 6305/4-2 S was spudded with the dynamic positioning drilling vessel West Navigator on 4 November 2010 and drilled to TD at 2985 m (2905 m TVD) in the Late Cretaceous Nise Formation. Ormen Lange appraisal well 6305/4-2 S encountered challenges while drilling the deeper sections. Some cavings were observed in the 17.5" section through Brygge Formation. TD was therefore called shallower due to a rump up in pore pressure. Tight spots and cavings were also observed while drilling the 8.5"section. During the first wire line 8.5" logging run, the string became differentially stuck and fishing operations were required to retrieve the string. The well was drilled with seawater/PHB sweeps and displacement mud down to 1738.5 m and with Aqua-Drill Deepwater mud from 1738.5 m to TD.
    Top of the Egga Reservoir Unit was encountered at 2835 m (2768.3 m TVD), 2.7 m shallow to prognosis. The base was penetrated at 2864 m (2794.5 m TVD) giving 27.3 m TVD gross reservoir. Of this 22.7 m TVD was net reservoir. The reservoir properties were as prognosed; average porosity and permeability was 27% and 261.5 mD respectively. The reservoir was water bearing and the pressure (298.4 bar) indicated high pressured water, most likely marginally depleted, and supported a hydrodynamic aquifer model. The results confirmed the interpretation of the seismic Direct Hydrocarbon Indication (DHI) in the area as a paleo-gas/water contact (i.e. DHI is not the current field outline).
    A total of 42.94 m of cores were cut in three cores. Cores 1 and 2 were cut in the interval 2844 m to 2901.5 m and core 3 from 2879 m to 2901.5 m. The overall recovery was 98.7%. No wire line fluid samples were taken. Seventy-three mud gas samples were captured in isotubes.
    The well was permanently abandoned on 11 February 2011 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]
    1740.00
    2984.00

  • 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
    2844.2
    2856.0
    [m ]
    2
    2858.0
    2865.0
    [m ]
    3
    2879.0
    2903.0
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    42.8
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Lithostratigraphy
    Lithostratigraphy
    Top depth [mMD RKB]
    Lithostrat. unit
    1122
    1122
    1718
    1771
    1771
    2389
    2389
    2567
    2835
    2878
    2878
    2938

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    FMI PPC MSIP
    2675
    2730
    GPIT MSIP PPC PEX
    2210
    2686
    HRLA CMR PEX ECS HNGS
    2665
    2869
    MWD - ARC
    1122
    2682
    MWD - TELE ECO GVR
    2682
    2985
    MWD - TELE ECO STETH
    2682
    2973

  • 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
    1196.0
    36
    1207.0
    0.00
    LOT
    SURF.COND.
    20
    1732.0
    26
    1738.0
    1.32
    LOT
    INTERM.
    13 3/8
    2231.0
    17 1/2
    2231.0
    1.47
    LOT
    INTERM.
    9 5/8
    2681.0
    12 1/4
    2682.0
    1.50
    LOT
    OPEN HOLE
    2985.0
    8 1/2
    2985.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    1122
    1.03
    Seawater
    1739
    1.23
    Seawater
    1739
    1.03
    Seawater
    2231
    1.28
    Seawater
    2859
    1.36
    Aqua Drill DW
    2902
    1.36
    Aqua Drill DW
    2930
    1.36
    Aqua Drill DW
    2985
    1.03
    Seawater
    2985
    1.03
    Seawater
    2985
    1.36
    Aqua Drill DW
    2985
    1.36
    Aqua Drill DW

  • 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
    0.28