Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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22.12.2024 - 01:25
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6605/8-2

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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.
    6605/8-2
    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.
    6605/8-2
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    NH0202R06&inline 4202 & crossline 4591
    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.
    StatoilHydro Petroleum 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.
    1181-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.
    61
    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,
    11.05.2008
    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.
    10.07.2008
    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.
    10.07.2010
    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.
    01.08.2010
    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.
    818.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4210.0
    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).
    4196.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    12.6
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    144
    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.
    LANGE FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    66° 18' 43.6'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    5° 31' 43.7'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7357177.73
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    613350.28
    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.
    5812

  • Wellbore history
    General
    Well 6605/8-2 was drilled in 818 m water depth ca 6 km south-south west of the Stetind discovery well 6605/8-1 in the Vøring Basin of the Norwegian Sea. The main objective of the well was to prove and test hydrocarbons with focus on reservoir and production properties. The main target was sandstone of the Lysing Formation, estimated to be up to 70 m thick with significantly improved reservoir quality compared to the 6605/8-1 well. The well was drilled up-flank of the first well, with the aim to find improved reservoir quality. The well was the second exploration well to be drilled on the Stetind prospect.
    Operations and results
    Wildcat well 6605/8-2 was spudded with the semi-submersible installation Transocean Leader on 11 May 2008 and drilled to TD at 4210 m (4196 m TVD) in Late Turonian sediments of the Lange Formation. A 9 7/8" pilot hole was drilled to 2017.0 m in order to check for shallow gas or shallow water flow. Neither shallow gas nor shallow water flow was observed. No sirious problems were experienced in the operations, but some deviation around 3000 m led to a slight difference between MD and TVD (14 m at TD). Further, the MDT tool got stuck after a mini DST. The well was drilled with seawater and hi-vis sweeps down to 1290 m, with seawater/hi-vis sweeps/Glydril mud from 1290 m to 2850 m, and with oil based Paratec mud from 2850 m to TD.
    The well penetrated rocks of Quaternary, Tertiary and Cretaceous age. The sandstones of the Lysing Formation had a gross thickness of 39 m; net to gross is 50%, total porosity 15% and water saturation 90%. The reservoir was thinner and of poorer quality than prognosed. The prognosed up-dip improvement in reservoir quality compared to the Stetind-1 well was not proved.
    Oil shows were as follows: Cut fluorescence with a faint petroleum odour was recorded at 2469 - 2505 m; good direct and cut fluorescence, and residual fluorescence was recorded at 2870 - 2874 m; rare traces of weak direct fluorescence were recorded at 3884 - 3893 m; and direct patchy (20%) fluorescence, no cut, was recorded at 3921 - 3922 m. fluorescence.
    Three conventional cores were cut from 3893 to 3942 m in the Lysing Formation. MDT fluid samples were taken at 3897.5 m during a mini-DST. Due to stucking and fortunately successful fishing of the tool, the mini-DST gave the temperature readings with longest time since circulations, 96 hours or more (time before the MDT was fished out). This temperature was 135 deg C, measured at 3884.6 m TVD RKB, giving a gradient of 44.9 deg C/km, assuming -1.5 deg C at sea floor.
    The well was permanently abandoned on 10 July 2008 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]
    2020.00
    4210.00

  • 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
    3893.0
    3920.6
    [m ]
    2
    3921.0
    3928.2
    [m ]
    3
    3929.0
    3941.8
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    47.5
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.53

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    txt
    0.00
    txt
    0.20

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    AIT DSI PEX ACTS ECRD
    3400
    4010
    DSI HRLA PEX
    2004
    2825
    MDT (EDTA GR ACTS ECRD)
    3886
    4034
    MDT (MRCS MRPO MRPA MRPS MRHY
    3886
    4034
    MDT (MRPO LFA MRSC MRMS MRPC
    3886
    4034
    MWD - ARC
    937
    2017
    MWD - ARC
    2010
    2850
    MWD - ARC
    3715
    4210
    MWD - ARC SON
    2850
    3715
    MWD - DIR
    841
    937
    MWD - DIR PWD
    937
    2010
    ZO VSP
    1640
    4130

  • 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
    931.0
    36
    932.0
    0.00
    LOT
    SURF.COND.
    20
    2004.0
    26
    2004.0
    0.00
    LOT
    INTERM.
    13 3/8
    2839.0
    17
    2847.0
    1.49
    LOT
    INTERM.
    9 5/8
    3713.0
    12 1/4
    3715.0
    1.73
    LOT
    OPEN HOLE
    4210.0
    8 1/2
    4210.0
    1.83
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    934
    1.35
    19.0
    Glydril
    1100
    1.40
    24.0
    Glydril
    1290
    1.35
    17.0
    Glydril
    2145
    1.31
    21.0
    Glydril
    2385
    1.32
    23.0
    Glydril
    2586
    1.34
    23.0
    Glydril
    2650
    1.34
    22.0
    Glydril
    2715
    1.52
    29.0
    Paratec
    2719
    1.37
    25.0
    Glydril
    2765
    1.37
    23.0
    Glydril
    2804
    1.37
    21.0
    Glydril
    2836
    1.37
    20.0
    Glydril
    2850
    1.40
    22.0
    Glydril
    2853
    1.46
    25.0
    Paratec
    2859
    1.46
    25.0
    Paratec
    2885
    1.45
    26.0
    Paratec
    3120
    1.45
    26.0
    Paratec
    3214
    1.45
    27.0
    Paratec
    3353
    1.45
    24.0
    Paratec
    3424
    1.52
    26.0
    Paratec
    3565
    1.52
    28.0
    Paratec
    3700
    1.52
    27.0
    Paratec
    3715
    1.52
    27.0
    Paratec
    3718
    1.63
    27.0
    Paratec
    3745
    1.68
    27.0
    Paratec
    3893
    1.68
    26.0
    Paratec
    3893
    1.68
    26.0
    Paratec
    3916
    1.68
    25.0
    Paratec
    3922
    1.68
    25.0
    Paratec
    3929
    1.68
    25.0
    Paratec
    3941
    1.68
    26.0
    Paratec
    3945
    1.68
    26.0
    Paratec
    3990
    1.68
    26.0
    Paratec
    4045
    1.68
    25.0
    Paratec
    4100
    1.68
    25.0
    Paratec
    4200
    1.68
    26.0
    Paratec
    4210
    1.68
    26.0
    Paratec