Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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27.12.2024 - 01:25
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6506/9-1

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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.
    6506/9-1
    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).
    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
    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.
    6506/9-1
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    inline 1378-crossline 1641 (MN9602R07)
    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.
    Total E&P Norge 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.
    1214-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.
    239
    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,
    20.01.2009
    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.
    15.09.2009
    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.
    15.09.2011
    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.
    28.09.2011
    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.
    NO
    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.
    MIDDLE JURASSIC
    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.
    ILE FM
    2nd level with HC, age
    Age of lithostratigraphic unit, 2nd level, where hydrocarbons were encountered. Examples of legal values: CRETACEOUS, EARLY CRETACEOUS, LATE JURASSIC, EOCENE.
    EARLY JURASSIC
    2nd level with HC, formation
    Name of lithostartigraphic unit, 2nd 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.
    TILJE FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    39.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    416.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    5664.0
    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).
    5659.7
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    4.3
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    205
    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.
    EARLY JURASSIC
    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.
    ÅRE FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    65° 29' 57.31'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    6° 56' 12.98'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7265844.08
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    404541.06
    UTM zone
    Universal Transverse Mercator zone. Examples of legal values: 31, 32, 33, 34.
    32
    NPDID wellbore
    Norwegian Offshore Directorate's unique id for the wellbore.
    5980

  • Wellbore history
    General
    Well 6506/9 ‐ 1 was drilled to further evaluate the Victoria discovery. The discovery was proven by well 6506/6-1 in 2000 in Lower to Middle Jurassic reservoir rocks, and is located about 22 kilometres northwest of the Heidrun field in the Norwegian Sea.
    The objective was to reduce uncertainties on fluid contacts, reservoir structure and reservoir quality, to prove well productivity and obtain reliable fluid samples from the Garn, Ile, Tilje and Åre reservoirs of Victoria.
    Operations and results
    Appraisal well 6506/9 ‐ 1 was spudded with the semi-submersible installation West Phoenix on 20 January 2009 and drilled to TD at 5664 m in the Early Jurassic Åre Formation. The well was drilled without significant problems, although wire line logging and sampling at TD was problematic due to high temperatures. The well was drilled with spud mud down to 1510 m, with NABM (non-aqueous based, or oil based mud) from 1510 to 5022 m, and with WARP (Weight Additive Research Project) NABM mud from 5022 m to TD.
    All the reservoirs were drilled in the 8 1/2" section, and confirmed to be gas bearing. However, reservoirs characteristics were poor, except in a few metric layers. The Garn Formation (5212 to 5277 m) was composed of very tight sandstones with quartzite cement. Maximum gas shows were 2.2% total gas at 5232 m. In the Ile Formation the gas shows were quite constant along the whole formation with limited values due to the coring operations. Maximum values in porous layers were between 1.35 and 3.52 % total gas. In the Tilje Formation, the overall reservoir characteristics were better with a maximum of 5.84% total gas at 5488m. At the base of the Tilje, below 5534 m, formation gas decreased to less than 1% total gas, linked to reservoir characteristics decrease. The Åre Formation consisted of mainly siltstones
    and silty claystones with poor reservoir characteristics in its upper part (maximum 1.68% TG). The lower half of the Åre Formation, composed of very hard poorly sorted sandstones, had very poor reservoir characteristics. Maximum gas show was 3.85% total gas at 5653m.
    Petrophysical analysis showed that the Jurassic reservoirs Garn, Ile, Tofte, Tilje and Åre were all gas bearing with a total Net to Gross of 18%, corresponding to 81m of Net. The effective porosity average in the Net interval was 12.4 %. Both Ile and Tilje Formations were encountered in a Gas ‐ Down ‐ To/Water ‐ Up ‐ To configuration. The Ile Formation has GDT at 5297 m and WUT at 5325 m. The Tilje Formation had GDT at 5515 m and WUT at 5523 m. No oil shows were reported from the well.
    Five cores were acquired in the Ile, Tilje and Åre Formations. The Ile Formation (5294 m to 5358 m) was nearly entirely cored. The Tilje Formation (5435 m to 5572 m) was cored from 10 m below the top of Tilje Formation when gas bearing sandstones were confirmed. The Åre Formation (5572 m to well TD) was cored in its upper section, represented mainly by siltstones and silty claystones, with poor reservoir characteristics (maximum 1.68% total gas).
    Wire line logging was performed to evaluate the different reservoirs. After one run in 12 1/4" section, a total of 20 runs were performed in the 8 1/2" section for reservoir evaluation, formation pressure measurement and sampling. Due to the high temperature expected at Victoria well TD, a series of special MDT tools, capable to work at 210 deg C, were prepared in the framework of a R&D project between TOTAL and Schlumberger to obtain formation pressure measurements and fluid samples. Although repeated attempts were done, the performances were poor due to low permeability reservoir and tool failures. Fluid samples of questionable quality were obtained at four depths: 5294.8 m (dry gas contaminated by base oil), 5341.7 m (base oil, some gas, and a few ml of water), 5479.0 m (mud, base oil and some gas), and at 5538.5 m (mud filtrate and small volumes of water - no trace of gas)
    The well was permanently abandoned on 15 September 2009 as a gas appraisal well.
    Testing
    The well was perforated in Upper and Middle Tilje (5431 m ? 5515 m) and a successful DST was carried out. The maximum production rate was 180 000 Sm3/day through a 16/64-inch nozzle. On average the well produced ca 170 000 Sm3 gas and 15 - 20 Sm3 water day. The average gas composition roughly recorded during the test was 88% methane, 11% CO2, and ca 30 ppm H2S. No trace of condensate was seen. No temperature measurement is available from the test.

  • 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]
    1510.00
    5664.00

  • 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
    5289.0
    5316.6
    [m ]
    2
    5316.6
    5353.2
    [m ]
    3
    5446.8
    5501.7
    [m ]
    4
    5502.0
    5530.8
    [m ]
    5
    5531.0
    5613.8
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    230.7
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.81

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    5431
    5515
    6.3
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    27.000
    40.000
    Drill stem tests (DST)
    Test number
    Oil
    [Sm3/day]
    Gas
    [Sm3/day]
    Oil density
    [g/cm3]
    Gas grav. rel.air
    GOR
    [m3/m3]
    1.0
    180000

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CALI
    452
    4911
    LWD - DIR
    455
    564
    LWD - GR RES PWD DIR
    564
    5664
    PO PQ HY PO LFA MS SC PC HTC EDT
    5294
    5294
    PPC HDSI GPIT HLDS HAPS GR ECRI
    455
    5010
    PPC HDSI PPC HNGS RDTC ECRI
    5006
    5662
    PQ HY PO SC MS GR ECRI
    5341
    5538
    PQ HY PO SC MS GR ECRI
    5341
    5341
    QAIT QSLT HTGC ECRI
    5006
    5663
    QAST-VSP
    511
    5575
    QLDT QCNT GR ECRI
    5006
    5665
    QSLT EDTC HTCS ECRI
    3535
    4989
    SC PA PO MS GR ECRI
    5479
    5539
    XPT HGR ECRI
    5538
    5605
    XPT HTGC ECRI
    5294
    5541
    XPT HTGC ECRI
    5294
    5655

  • 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
    558.0
    36
    564.0
    0.00
    LOT
    SURF.COND.
    20
    1501.0
    26
    1510.0
    0.00
    LOT
    INTERM.
    13 3/8
    3532.0
    16
    3555.0
    0.00
    LOT
    INTERM.
    9 7/8
    5009.0
    12 1/4
    5022.0
    1.96
    LOT
    LINER
    7
    5562.0
    8 1/2
    5564.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    495
    1.03
    10.0
    ManualEntry
    665
    1.60
    51.0
    ManualEntry
    1282
    1.21
    6.0
    ManualEntry
    1500
    1.30
    11.0
    ManualEntry
    1510
    1.30
    ManualEntry
    1884
    1.60
    46.0
    ManualEntry
    2334
    1.89
    74.0
    ManualEntry
    2789
    1.60
    46.0
    ManualEntry
    3355
    1.60
    39.0
    ManualEntry
    3623
    1.80
    56.0
    ManualEntry
    3926
    1.80
    44.0
    ManualEntry
    4139
    1.83
    49.0
    ManualEntry
    4774
    1.87
    49.0
    ManualEntry
    4780
    1.74
    10.0
    ManualEntry
    5022
    1.71
    47.0
    ManualEntry
    5066
    1.70
    36.0
    ManualEntry
    5289
    1.70
    38.0
    ManualEntry
    5308
    1.74
    10.0
    ManualEntry
    5385
    1.74
    10.0
    ManualEntry
    5502
    1.70
    45.0
    ManualEntry
    5560
    1.70
    64.0
    ManualEntry
    5664
    1.77
    10.0
    ManualEntry