Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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23.07.2024 - 01:26
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6604/10-1

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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.
    6604/10-1
    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
    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.
    6604/10-1
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    inline 2462 & xline 3306 on sh0903 3D Volume
    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.
    1307-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.
    101
    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,
    26.05.2010
    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.
    03.09.2010
    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.
    01.01.2012
    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.
    01.01.2012
    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.
    GAS
    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.
    YES
    1st level with HC, age
    Age of lithostratigraphic unit, 1st level, where hydrocarbons were encountered. Examples of legal values: CRETACEOUS, EARLY CRETACEOUS, LATE JURASSIC, EOCENE. See also Norwegian Offshore Directorate bulletins.
    LATE CRETACEOUS
    1st level with HC, formation
    Name of lithostartigraphic unit, 1st level, where hydrocarbons were encountered. Shown only for released wells. Examples of legal values: BASEMENT, COOK FM, EKOFISK FM, HEIMDAL FM, SANDNES FM, SOGNEFJORD FM, TARBERT FM, BRENT GP. See also Norwegian Offshore Directorate bulletins.
    SHETLAND GP
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    40.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    1354.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3715.0
    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).
    3715.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    2
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    129
    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.
    66° 11' 0.1'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    4° 11' 42.79'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7341048.53
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    553857.27
    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.
    6356
  • Wellbore history

    General
    Well 6604/10-1 was drilled to appraise the 6603/12-1 Gro gas discovery in the Vigrid Syncline in the Vøring Basin of the Norwegian Sea. Before 6604/10-1 was drilled, resource estimates for the discovery were between 10 and 100 billion standard cubic metres (Sm3) of recoverable gas.
    Operations and results
    Appraisal well 6604/10-1 was spudded with the semi-submersible installation Aker Barents on 26 May 2010 and drilled to TD at 3715 m in the Late Cretaceous Springar Formation. No pilot hole was drilled and no shallow gas or shallow water flow was encountered in this well, as predicted. When running the BOP a leak in the mini connector on choke line was discovered. The well was suspended for seven days while this was repaired. The well was drilled with seawater and hi-vis pills down to 2320 m, with Glydril mud from 2320 m to 2848 m, and with Paratherm oil based mud from 2848 m to TD.
    The well penetrated rocks of Quaternary, Tertiary and Cretaceous age. Top Maastrichtian Springar reservoir came in at 3597.2 m, 36.8 m shallower than the pre-drill prediction. Based on poor MDT pressure data it appears that the upper reservoir unit (3597 - 3616 m) and the middle reservoir unit (3616 - 3626 m) are different pressure regimes. No valid pressures were obtained in the lower unit (3626 - 3648 m). After analysing the acquired data it was concluded that the upper interval of the Springar reservoir was gas bearing. The reservoir quality was in general very poor, apart from a short section near the very top. No staining or fluorescence on cuttings was detected throughout the 6604/10-1 well. The hydrocarbon core scanner detected "heavy oil" between 3601 and 3621, but this is not confirmed by other data. The well was re-classified as a wildcat well, as it proved two minor deposits which are not in communication with 6603/12-1 Gro gas discovery.
    One 54 m core was taken from the reservoir interval 3601.4 to 3655.4 m (3598.8 to 3652.8 m wire line depth) with 100% recovery. An extensive wire line program was successfully carried out after reaching TD. Two MDT runs were made and only two valid and three slightly supercharged pressure points out of 35 tests were obtained. MDT fluid samples were taken at 3601.8 m (gas), 3613.0 m (gas/water), and at 3617 m (gas/water/filtrate). PVT analyses of the gas samples show a higher liquid content than in the 6603/12-1 gas, but it is not possible to exclude OBM contamination as the cause of this difference.
    The well was permanently abandoned on 3 September as a gas discovery.
    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]
    2335.00
    3715.00
  • 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
    3601.4
    3655.3
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    53.9
    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
    2695.0
    [m]
    DC
    PETROSTA
    2715.0
    [m]
    DC
    PETROS
    2745.0
    [m]
    DC
    PETROS
    2805.0
    [m]
    DC
    PETROS
    2825.0
    [m]
    DC
    PETROS
    2845.0
    [m]
    DC
    PETROS
    2875.0
    [m]
    DC
    PETROS
    2945.0
    [m]
    DC
    PETROS
    2965.0
    [m]
    DC
    PETROS
    2985.0
    [m]
    DC
    PETROS
    3005.0
    [m]
    DC
    PETROS
    3025.0
    [m]
    DC
    PETROS
    3045.0
    [m]
    DC
    PETROS
    3065.0
    [m]
    DC
    PETROS
    3075.0
    [m]
    DC
    PETROS
    3095.0
    [m]
    DC
    PETROS
    3115.0
    [m]
    DC
    PETROS
    3135.0
    [m]
    DC
    PETROS
    3155.0
    [m]
    DC
    PETROS
    3175.0
    [m]
    DC
    PETROS
    3195.0
    [m]
    DC
    PETROS
    3215.0
    [m]
    DC
    PETROS
    3235.0
    [m]
    DC
    PETROS
    3265.0
    [m]
    DC
    PETROS
    3285.0
    [m]
    DC
    PETROS
    3305.0
    [m]
    DC
    PETROS
    3325.0
    [m]
    DC
    PETROS
    3345.0
    [m]
    DC
    PETROS
    3470.0
    [m]
    DC
    PETROS
    3480.0
    [m]
    DC
    PETROS
    3490.0
    [m]
    DC
    PETROS
    3495.0
    [m]
    DC
    PETROS
    3505.0
    [m]
    DC
    PETROS
    3510.0
    [m]
    DC
    PETROS
    3515.0
    [m]
    DC
    PETROS
    3525.0
    [m]
    DC
    PETROS
    3530.0
    [m]
    DC
    PETROS
    3540.0
    [m]
    DC
    PETROS
    3545.0
    [m]
    DC
    PETROS
    3550.0
    [m]
    DC
    PETROS
    3555.0
    [m]
    DC
    PETROS
    3575.0
    [m]
    DC
    PETROS
    3603.0
    [m]
    C
    PETROS
    3605.0
    [m]
    C
    PETROS
    3605.4
    [m]
    C
    PETROS
    3607.8
    [m]
    C
    PETROS
    3608.6
    [m]
    C
    PETROS
    3611.8
    [m]
    C
    PETROS
    3614.9
    [m]
    C
    PETROS
    3616.6
    [m]
    C
    PETROS
    3618.2
    [m]
    C
    PETROS
    3618.5
    [m]
    C
    PETROS
    3618.7
    [m]
    C
    PETROS
    3618.9
    [m]
    C
    PETROS
    3621.5
    [m]
    C
    PETROS
    3624.9
    [m]
    C
    PETROS
    3625.1
    [m]
    C
    PETROS
    3628.7
    [m]
    C
    PETROS
    3628.8
    [m]
    C
    PETROS
    3630.3
    [m]
    C
    PETROS
    3633.3
    [m]
    C
    PETROS
    3637.8
    [m]
    C
    PETROS
    3639.5
    [m]
    C
    PETROS
    3640.8
    [m]
    C
    PETROS
    3642.8
    [m]
    C
    PETROS
    3643.5
    [m]
    C
    PETROS
    3644.8
    [m]
    C
    PETROS
    3648.2
    [m]
    C
    PETROS
    3648.9
    [m]
    C
    PETROS
    3649.4
    [m]
    C
    PETROS
    3650.6
    [m]
    C
    PETROS
    3651.5
    [m]
    C
    PETROS
    3652.5
    [m]
    C
    PETROS
    3653.5
    [m]
    C
    PETROS
    3654.5
    [m]
    C
    PETROS
    3660.0
    [m]
    DC
    PETROS
    3665.0
    [m]
    DC
    PETROS
    3670.0
    [m]
    DC
    PETROS
    3675.0
    [m]
    DC
    PETROS
    3680.0
    [m]
    DC
    PETROS
    3685.0
    [m]
    DC
    PETROS
    3690.0
    [m]
    DC
    PETROS
    3695.0
    [m]
    DC
    PETROS
    3700.0
    [m]
    DC
    PETROS
    3705.0
    [m]
    DC
    PETROS
    3710.0
    [m]
    DC
    PETROS
    3715.0
    [m]
    DC
    PETROS
  • Lithostratigraphy

    Lithostratigraphy
    Top depth [mMD RKB]
    Lithostrat. unit
    1385
    1385
    1578
    2075
    2075
    2673
    2673
    2950
    3371
    3371
    3597
    3645
  • Logs

    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    AIT DSI PPC
    2320
    3711
    HNGS PEX
    3450
    3711
    MDT DP GR
    3613
    3617
    MDT GR
    3601
    3617
    MR SCANN
    3591
    3675
    MWD ARC
    1466
    2856
    MWD ARC
    3656
    3715
    MWD ARC RAB
    3470
    3601
    MWD ARC SON VISION
    2856
    3470
    VSP
    1400
    3702
  • 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
    1465.0
    42
    1466.0
    0.00
    LOT
    SURF.COND.
    20
    2320.0
    26
    2326.0
    1.28
    LOT
    INTERM.
    13 3/8
    2848.0
    17 1/2
    2855.0
    1.27
    LOT
    LINER
    9 5/8
    3468.0
    12 1/4
    3470.0
    1.39
    LOT
    OPEN HOLE
    3715.0
    8 1/2
    3715.0
    0.00
    LOT
  • Drilling mud

    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    1419
    1.02
    Other
    2326
    1.12
    Glydril
    2326
    1.12
    Glydril
    2326
    1.39
    PAD
    2855
    1.17
    Glydril
    2855
    1.21
    Glydril
    2855
    1.21
    Glydril
    2855
    1.17
    Glydril
    3320
    1.22
    Paratherm
    3470
    1.25
    Paratherm
    3470
    1.25
    Paratherm
    3520
    1.31
    Paratherm
    3601
    1.28
    Paratherm
    3715
    1.18
    Glydril
    3750
    1.17
    Glydril
  • 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
    0.23