Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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15.07.2024 - 01:28
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6305/1-1

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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.
    6305/1-1
    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
    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
    Well name
    Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    6305/1-1
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    NH 9602- INLINE 2016 & X-LINE 6916
    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.
    Norsk Hydro Produksjon 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.
    935-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.
    91
    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,
    18.08.1998
    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.
    19.11.1998
    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.
    19.11.2000
    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.
    18.12.2002
    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.
    23.5
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    839.5
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4560.0
    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).
    4546.0
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    141
    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.
    LYSING FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    63° 46' 59.72'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    5° 16' 19.57'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7075028.48
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    611981.31
    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.
    3555
  • Wellbore history

    General
    Well 6305/1-1 is located in the northern part of the Ormen Lange Dome and was the third well drilled on the Ormen Lange Structure, following the two successful wells 6305/5-1 drilled by Hydro in 1997 and 6305/7-1 drilled by BP in 1998. The Egga sand in the Tang Formation was the main target for the well. The sand was predicted to contain gas. The Tare and Lysing Formations were considered as secondary and third target levels, respectively.
    Operations and results
    Wildcat well 6305/1-1 was spudded in a water depth of 863 m on 18 August 1998 with the semi-submersible installation "Transocean Leader" and drilled to a total depth of 4565 m (4551 m TVD) in Late Cretaceous sediments of the Lysing Formation. Well 6305/1-1 was drilled to 2560 m where hole problems made it necessary to plug the well back and perform a technical, sidetrack from 2467 m. The well was drilled with spud mud down to 1610 m and with "Aquacol" KCl/Polymer mud from 1610 to TD. The Egga Member of the Tang Formation and thin sandstones in the Springar Formation were proven in cores from 2558-2623,5 m. Egga sand was encountered even though the reservoir quality was poorer than prognosed. No moveable hydrocarbons were encountered in well 6305/1-1, but weak residual shows were reported in almost the entire Cretaceous section. The Egga sand in well 6305/1-1 proved to be over pressured compared to wells 6305/5-1 and 6305/7-1. Even though some sand was reported from the mud geologist at the predicted intra Tare level this was not considered as a reservoir sand. At Lysing level some thin sandstone layers were encountered, but not considered as a reservoir. Five cores were cut in the well. Four were cut in the Tang and Springar Formations in the interval 2556 m to 2628 m. Recovery for these varied from 10 % to 95 %. The fifth core was cut in the upper part of the Lysing Formation in the interval 3646 m to 3670.5 m. Recovery for this core was 97 %. An MDT fluid sample was taken at 2567.7 m. It contained formation water. The well was permanently plugged and abandoned as a dry well on 19 November 1998.
    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]
    1620.00
    4555.00
  • 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
    2556.0
    2573.2
    [m ]
    2
    2574.0
    2582.2
    [m ]
    3
    2601.0
    2601.9
    [m ]
    4
    2610.0
    2623.2
    [m ]
    5
    3643.0
    3669.6
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    66.0
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES
  • Core photos

    Core photos
    Core photo at depth: 2556-2561m
    Core photo at depth: 2561-2566m
    Core photo at depth: 2566-2571m
    Core photo at depth: 2571-2573m
    Core photo at depth: 2574-2579m
    2556-2561m
    2561-2566m
    2566-2571m
    2571-2573m
    2574-2579m
    Core photo at depth: 2579-2582m
    Core photo at depth: 2601-2602m
    Core photo at depth: 2610-2615m
    Core photo at depth: 2615-2620m
    Core photo at depth: 2620-2623m
    2579-2582m
    2601-2602m
    2610-2615m
    2615-2620m
    2620-2623m
    Core photo at depth: 3643-3648m
    Core photo at depth: 3648-3653m
    Core photo at depth: 3653-3658m
    Core photo at depth: 3658-3663m
    Core photo at depth: 3663-3668m
    3643-3648m
    3648-3653m
    3653-3658m
    3658-3663m
    3663-3668m
    Core photo at depth: 3668-3670m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    3668-3670m
  • Palynological slides at the Norwegian Offshore Directorate

    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1630.0
    [m]
    DC
    RRI
    1649.0
    [m]
    SWC
    RRI
    1660.0
    [m]
    DC
    RRI
    1667.5
    [m]
    SWC
    RRI
    1690.0
    [m]
    DC
    RRI
    1715.0
    [m]
    SWC
    RRI
    1720.0
    [m]
    DC
    RRI
    1730.0
    [m]
    DC
    RRI
    1739.0
    [m]
    SWC
    RRI
    1753.0
    [m]
    SWC
    RRI
    1778.0
    [m]
    SWC
    RRI
    1793.0
    [m]
    SWC
    RRI
    1813.0
    [m]
    SWC
    RRI
    1850.0
    [m]
    DC
    RRI
    1879.0
    [m]
    SWC
    RRI
    1880.0
    [m]
    DC
    RRI
    1912.0
    [m]
    SWC
    RRI
    1935.0
    [m]
    SWC
    RRI
    1948.0
    [m]
    SWC
    RRI
    1956.0
    [m]
    SWC
    RRI
    1965.0
    [m]
    SWC
    RRI
    1977.0
    [m]
    SWC
    RRI
    1990.0
    [m]
    DC
    RRI
    2008.0
    [m]
    SWC
    RRI
    2015.0
    [m]
    SWC
    RRI
    2024.0
    [m]
    SWC
    RRI
    2053.0
    [m]
    SWC
    RRI
    2060.0
    [m]
    SWC
    RRI
    2071.5
    [m]
    SWC
    RRI
    2078.0
    [m]
    SWC
    RRI
    2087.0
    [m]
    SWC
    RRI
    2103.0
    [m]
    SWC
    RRI
    2112.0
    [m]
    SWC
    RRI
    2117.0
    [m]
    SWC
    RRI
    2142.0
    [m]
    SWC
    RRI
    2149.0
    [m]
    SWC
    RRI
    2165.0
    [m]
    SWC
    RRI
    2198.0
    [m]
    SWC
    RRI
    2208.0
    [m]
    SWC
    RRI
    2225.0
    [m]
    SWC
    RRI
    2235.0
    [m]
    SWC
    RRI
    2470.0
    [m]
    DC
    RRI
    2500.0
    [m]
    DC
    RRI
    2525.0
    [m]
    DC
    RRI
    2535.0
    [m]
    DC
    RRI
    2540.0
    [m]
    DC
    RRI
    2542.0
    [m]
    DC
    RRI
    2545.0
    [m]
    DC
    RRI
    2547.0
    [m]
    DC
    RRI
    2552.0
    [m]
    DC
    RRI
    2650.0
    [m]
    DC
    RRI
    2675.0
    [m]
    DC
    RRI
    2690.0
    [m]
    DC
    RRI
    2705.0
    [m]
    DC
    RRI
    2715.0
    [m]
    DC
    RRI
    2725.0
    [m]
    DC
    RRI
    2730.0
    [m]
    DC
    RRI
    2770.0
    [m]
    DC
    RRI
    2820.0
    [m]
    DC
    RRI
  • Lithostratigraphy

  • Composite logs

    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.57
  • 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
    182.80
    .pdf
    6.65
  • Logs

    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CMR GR
    2540
    2645
    CST GR
    2432
    4550
    CST GR AMS
    1628
    2235
    DSI FMI CAL
    1900
    2544
    FMI HNGS AMS
    2414
    3011
    HALS TLD HGNS DSI GPIT AMS
    839
    2235
    HALS TLD HGNS DSI GPIT AMS
    2350
    4550
    MDT GR
    2557
    2864
    MWD-MPRLITE/DPR
    863
    4560
    VSP
    1840
    4560
  • 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
    942.0
    36
    942.0
    0.00
    LOT
    INTERM.
    20
    1605.0
    26
    1605.0
    1.47
    LOT
    INTERM.
    13 3/8
    2414.0
    17 1/2
    2414.0
    1.63
    LOT
    INTERM.
    9 5/8
    3004.0
    12 1/4
    3004.0
    1.68
    LOT
    OPEN HOLE
    4560.0
    8 1/2
    4560.0
    0.00
    LOT
  • Drilling mud

    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    889
    1.10
    WATER BASED
    945
    1.10
    WATER BASED
    946
    1.20
    WATER BASED
    1600
    1.38
    18.0
    WATER BASED
    1610
    1.20
    WATER BASED
    1615
    1.32
    16.0
    WATER BASED
    2415
    0.00
    15.0
    WATER BASED
    2418
    1.30
    17.0
    WATER BASED
    2556
    1.45
    24.0
    WATER BASED
    2561
    1.42
    17.0
    WATER BASED
    2685
    1.45
    20.0
    WATER BASED
    2900
    1.46
    21.0
    WATER BASED
    2950
    1.48
    24.0
    WATER BASED
    3010
    1.50
    25.0
    WATER BASED
    3372
    1.47
    19.0
    WATER BASED
    4313
    1.47
    22.0
    WATER BASED
    4438
    1.47
    18.0
    WATER BASED
    4560
    1.47
    21.0
    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
    0.27