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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6305/9-1

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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.
    6305/9-1
    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
    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
    Well name
    Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    6305/9-1
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    NH-OLSE98R01-inline5170 & xline3865
    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.
    1008-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.
    23
    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,
    09.07.2001
    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.
    31.07.2001
    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.
    31.07.2003
    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.
    15.06.2005
    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.
    24.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    187.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2655.0
    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).
    2654.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    2.9
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    86
    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.
    SPRINGAR FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    63° 17' 59.96'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    5° 59' 14.63'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7022673.85
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    649731.56
    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.
    4297

  • Wellbore history
    General
    The exploration well 6305/9-1 was drilled on the "Blåveis" prospect in the southeastern part of the block, east of the Ormen Lange Field. The main objective of the well was to test if hydrocarbons were present in the Tertiary Egga Member in the Våle Formation, and in the Maastrichtian Springar Formation sandstones.
    Operations and results
    Wildcat well 6305/9-1 was spudded with the semi-submersible installation Transocean Arctic on 9 July 2001 and drilled to TD at 2655 m in the Late Cretaceous Springar Formation. The well was drilled with seawater and hi-vis pills down to 680 m and with GLYDRIL KCl/polymer mud from 680 m to TD.
    In the Lower Paleocene an Egga Member sandstone of the Våle Formation was found, with good sands that became increasingly interbedded with claystone towards top of the underlying Springar Formation. The clean sandstone intervals were high porosity - high permeability reservoirs. No hydrocarbon indications were observed. One core was cut in the Egga Member, covering 17.4 m of the 54 m thick sandstone. The core shows a deposition within stacked channels and related overbank areas of intraslope basin turbidite system. The reservoir properties in the cored interval show 27.5% porosity and 2280 mD permeability. No core was taken in the Springar Formation. The reservoir quality of the Springar Formation clean sands is about similar to the Egga Member but the net sand fraction is less. The geology of the well was very much as prognosed, especially the formation tops in the lower part of the well came in almost as prognosed. The formation pressure in the lower Tertiary was hydrostatic. Organic geochemical analysis showed vitrinite reflectance Ro values in the range of 0.35-0.40 for the Egga reservoir sandstone and Springar Formation, which means that source rocks at this level are thermally immature for hydrocarbon expulsion. Extracts from samples of the Egga Sandstone and Springar Formation gave only traces of early mature, locally derived hydrocarbons. No fluid sample was attempted.
    The well was permanently abandoned on 31 July 2001 as a dry hole.
    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]
    700.00
    2655.00

  • 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
    2477.0
    2494.4
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    17.4
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 2477-2478m
    Core photo at depth: 2478-2479m
    Core photo at depth: 2479-2480m
    Core photo at depth: 2480-2481m
    Core photo at depth: 2481-2482m
    2477-2478m
    2478-2479m
    2479-2480m
    2480-2481m
    2481-2482m
    Core photo at depth: 24822483m
    Core photo at depth: 2483-2484m
    Core photo at depth: 2484-2485m
    Core photo at depth: 2485-2486m
    Core photo at depth: 2486-2487m
    24822483m
    2483-2484m
    2484-2485m
    2485-2486m
    2486-2487m
    Core photo at depth: 2487-2488m
    Core photo at depth: 2488-2489m
    Core photo at depth: 2489-2490m
    Core photo at depth: 2490-2491m
    Core photo at depth: 2491-2492m
    2487-2488m
    2488-2489m
    2489-2490m
    2490-2491m
    2491-2492m
    Core photo at depth: 2492-2493m
    Core photo at depth: 2493-2494m
    Core photo at depth: 2494-2495M
    Core photo at depth:  
    Core photo at depth:  
    2492-2493m
    2493-2494m
    2494-2495M

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1210.0
    [m]
    DC
    RRI
    1230.0
    [m]
    DC
    RRI
    1250.0
    [m]
    DC
    RRI
    1510.0
    [m]
    DC
    RRI
    1530.0
    [m]
    DC
    RRI
    1560.0
    [m]
    DC
    RRI
    1580.0
    [m]
    DC
    RRI
    1600.0
    [m]
    DC
    RRI
    1620.0
    [m]
    DC
    RRI
    1640.0
    [m]
    DC
    RRI
    1660.0
    [m]
    DC
    RRI
    1680.0
    [m]
    DC
    RRI
    1700.0
    [m]
    DC
    RRI
    1720.0
    [m]
    DC
    RRI
    1740.0
    [m]
    DC
    RRI
    1760.0
    [m]
    DC
    RRI
    1780.0
    [m]
    DC
    RRI
    1800.0
    [m]
    DC
    RRI
    1820.0
    [m]
    DC
    RRI
    1840.0
    [m]
    DC
    RRI
    1860.0
    [m]
    DC
    RRI
    1880.0
    [m]
    DC
    RRI
    1900.0
    [m]
    DC
    RRI
    1920.0
    [m]
    DC
    RRI
    1940.0
    [m]
    DC
    RRI
    1960.0
    [m]
    DC
    RRI
    1980.0
    [m]
    DC
    RRI
    2010.0
    [m]
    DC
    RRI
    2030.0
    [m]
    DC
    RRI
    2050.0
    [m]
    DC
    RRI
    2070.0
    [m]
    DC
    RRI
    2090.0
    [m]
    DC
    RRI
    2110.0
    [m]
    DC
    RRI
    2130.0
    [m]
    DC
    RRI
    2150.0
    [m]
    DC
    RRI
    2170.0
    [m]
    DC
    RRI
    2190.0
    [m]
    DC
    RRI
    2210.0
    [m]
    DC
    RRI
    2230.0
    [m]
    DC
    RRI
    2250.0
    [m]
    DC
    RRI
    2270.0
    [m]
    DC
    RRI
    2290.0
    [m]
    DC
    RRI
    2310.0
    [m]
    DC
    RRI
    2322.0
    [m]
    DC
    RRI
    2340.0
    [m]
    SWC
    RRI
    2349.0
    [m]
    DC
    RRI
    2355.0
    [m]
    DC
    RRI
    2361.0
    [m]
    DC
    RRI
    2367.0
    [m]
    DC
    RRI
    2373.0
    [m]
    DC
    RRI
    2379.0
    [m]
    DC
    RRI
    2385.0
    [m]
    DC
    RRI
    2391.0
    [m]
    DC
    RRI
    2397.0
    [m]
    DC
    RRI
    2403.0
    [m]
    DC
    RRI
    2409.0
    [m]
    DC
    RRI
    2415.0
    [m]
    DC
    RRI
    2421.0
    [m]
    DC
    RRI
    2427.0
    [m]
    DC
    RRI
    2433.0
    [m]
    DC
    RRI
    2439.0
    [m]
    DC
    RRI
    2445.0
    [m]
    DC
    RRI
    2451.0
    [m]
    DC
    RRI
    2457.0
    [m]
    DC
    RRI
    2463.0
    [m]
    DC
    RRI
    2469.0
    [m]
    DC
    RRI
    2472.0
    [m]
    DC
    RRI
    2477.0
    [m]
    C
    RRI
    2496.0
    [m]
    DC
    RRI
    2496.0
    [m]
    DC
    RRI
    2505.0
    [m]
    DC
    RRI
    2505.0
    [m]
    SWC
    RRI
    2511.0
    [m]
    DC
    RRI
    2525.0
    [m]
    SWC
    RRI
    2527.5
    [m]
    SWC
    RRI
    2535.0
    [m]
    SWC
    RRI
    2540.0
    [m]
    SWC
    RRI
    2544.0
    [m]
    SWC
    RRI
    2548.0
    [m]
    SWC
    RRI
    2555.0
    [m]
    SWC
    RRI
    2559.0
    [m]
    DC
    RRI
    2565.0
    [m]
    SWC
    RRI
    2571.0
    [m]
    DC
    RRI
    2575.0
    [m]
    SWC
    RRI
    2580.0
    [m]
    DC
    RRI
    2590.0
    [m]
    SWC
    RRI
    2598.0
    [m]
    DC
    RRI
    2601.0
    [m]
    DC
    RRI
    2610.0
    [m]
    SWC
    RRI
    2619.0
    [m]
    DC
    RRI
    2628.0
    [m]
    DC
    RRI
    2631.0
    [m]
    DC
    RRI
    2637.0
    [m]
    DC
    RRI
    2643.0
    [m]
    DC
    RRI
    2649.0
    [m]
    DC
    RRI
    2650.0
    [m]
    SWC
    RRI
    2655.0
    [m]
    DC
    RRI

  • Lithostratigraphy
    Lithostratigraphy
    Top depth [mMD RKB]
    Lithostrat. unit
    211
    211
    1074
    1303
    1303
    1669
    1669
    1948
    2437
    2469
    2523
    2523

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.21

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    3.07

  • 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
    9.05
    .PDF
    1.82

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CMST GR
    2340
    2650
    DSI GR ACTS
    2068
    2653
    DUAL CSI-GR VSP
    1790
    2620
    MDT GR
    2474
    2548
    MWD LWD
    211
    274
    MWD LWD - ADN RAB
    2295
    2477
    MWD LWD - ADN RAB
    2460
    2654
    MWD LWD - CDR
    267
    671
    MWD LWD - CDR ISONIC
    674
    2290

  • 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
    272.0
    36
    272.0
    0.00
    LOT
    SURF.COND.
    20
    675.0
    26
    680.0
    1.50
    LOT
    INTERM.
    9 5/8
    2295.0
    12 1/4
    2305.0
    1.67
    LOT
    OPEN HOLE
    2655.0
    8 1/2
    2655.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    211
    1.05
    WATER BASED
    274
    1.05
    WATER BASED
    680
    1.05
    WATER BASED
    2138
    1.39
    23.0
    WATER BASED
    2195
    1.39
    23.0
    WATER BASED
    2305
    1.35
    22.0
    WATER BASED
    2477
    1.30
    22.0
    WATER BASED
    2580
    1.30
    19.0
    WATER BASED
    2655
    1.30
    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
    0.28