Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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19.07.2024 - 01:27
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35/11-15 S

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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.
    35/11-15 S
    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.
    NORTH SEA
    Field
    Name of the field the wellbore is related to.
    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.
    35/11-15
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    seismic survey MG0098R01 inline 1115 & crossline 1373
    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.
    1136-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.
    89
    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,
    01.04.2007
    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.
    28.06.2007
    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.
    28.06.2009
    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.
    28.06.2009
    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.
    OIL/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 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.
    INTRA HEATHER FM SS
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    26.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    363.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3250.0
    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).
    2987.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    61.2
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    123
    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.
    MIDDLE 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.
    HEATHER FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    61° 6' 50.28'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    3° 31' 19.94'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6775754.76
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    528143.88
    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.
    5517
  • Wellbore history

    General
    Well 35/11-15 S is an exploration well in the Fram/Astero area west of the Sognefjord. The well should test the H-Nord prospect in PL090, a 3-way closure located immediately north of the Fram Vest field. The objectives of the well were test the presence and type of hydrocarbons in the Oxfordian Turbidites J56, J54, and J52, and the J45 Callovian Turbidites. The prognosed TD was 3250 m or sufficient depth below Callovian Sandstone to get conclusive data with logging tools. If hydrocarbons were present, the well would be side tracked below the 9 5/8" casing and cores would be cut through the hydrocarbon column in the parallel well bore. An extended wire line-logging program and possibly production testing would be performed in a discovery case. The well actually resulted in five different well tracks. The lithostratigraphy given on this fact page is based on T1, the stratigraphically deepest track.
    Operations and results
    Well 35/11-15 S was spudded with the semi-submersible installation Transocean Winner on 1 April 2007 and drilled deviated to final TD in the T5 sidetrack at 3250 (2987 m TVD) in the Late Jurassic Heather Formation. The well was drilled as a deviated hole, with an angle of approximately 20 degrees through the reservoir section. After proving hydrocarbons in the target levels the T2 sidetrack kicked off from 2840 m below the 9 5/8" casing and drilled and cored to a total depth of 3213 m in the Heather Fm. A third sidetrack was decided to further appraise a thin oil zone in J56, seen in the T2 track. The two first attempts, T3 and T4, both with kick off at 2060 m were failures. T5 with kick off at 2163 m in T4 was successful. After reaching final TD in T5 severe hole problems occurred with the hole falling in/partially collapsing in the Cromer Knoll Group (2642 - 2660 m) and in the Draupne Formation (2860 - 2900 m). As a result no wire line logs were run below 2640 m in T5. The well was drilled with spud mud down to 467 m and with GLYDRIL KCl/polymer mud from 467 to TD in all well tracks.
    Several Tertiary sands without formalised formation names were penetrated. Top Viking Group, Draupne Formation, was encountered at 2697 m (2685.9 m TVD) in T1 and at 2722 m (2684.8 m TVD) in T5. The T1 track proved gas in J56, but the sand development was poor in this location. Oil was proven in J52, and the free water level here was defined at 2941 m TVD. The sidetracked well 35/11-15 S T5 proved oil in J56 in a more favourable position, with well developed sandstones. A probable oil contact was seen at 2950 m TVD. No shows were reported above the Viking Group.
    Two cores were cut in T2 from 2928 m to 2980.4 m. Three MDT fluid samples were acquired in T1: a gas sample at 2871.7 m, an oil sample at 2941.0 m, and a water sample at 2970.8 m.
    The well was permanently abandoned on 1 July 2007 as an oil and 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]
    565.00
    3240.00
  • 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
    2928.0
    2954.7
    [m ]
    2
    2955.0
    2980.4
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    52.1
    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
    595.0
    [m]
    DC
    FUGRO
    635.0
    [m]
    DC
    FUGRO
    675.0
    [m]
    DC
    FUGRO
    715.0
    [m]
    DC
    FUGRO
    755.0
    [m]
    DC
    FUGRO
    795.0
    [m]
    DC
    FUGRO
    835.0
    [m]
    DC
    FUGRO
    875.0
    [m]
    DC
    FUGRO
    915.0
    [m]
    DC
    FUGRO
    955.0
    [m]
    DC
    FUGRO
    995.0
    [m]
    DC
    FUGRO
    1035.0
    [m]
    DC
    FUGRO
    1075.0
    [m]
    DC
    FUGRO
    1115.0
    [m]
    DC
    FUGRO
    1155.0
    [m]
    DC
    FUGRO
    1195.0
    [m]
    DC
    FUGRO
    1235.0
    [m]
    DC
    FUGRO
    1275.0
    [m]
    DC
    FUGRO
    1315.0
    [m]
    DC
    FUGRO
    1355.0
    [m]
    DC
    FUGRO
    1395.0
    [m]
    DC
    FUGRO
    1435.0
    [m]
    DC
    FUGRO
    1475.0
    [m]
    DC
    FUGRO
    1515.0
    [m]
    DC
    FUGRO
    1545.0
    [m]
    DC
    FUGRO
    1575.0
    [m]
    DC
    FUGRO
    1605.0
    [m]
    DC
    FUGRO
    1635.0
    [m]
    DC
    FUGRO
    1665.0
    [m]
    DC
    FUGRO
    1681.0
    [m]
    DC
    FUGRO
    1700.0
    [m]
    DC
    FUGRO
    1730.0
    [m]
    DC
    FUGRO
    1760.0
    [m]
    DC
    FUGRO
    1790.0
    [m]
    DC
    FUGRO
    1820.0
    [m]
    DC
    FUGRO
    1850.0
    [m]
    DC
    FUGRO
    1880.0
    [m]
    DC
    FUGRO
    1910.0
    [m]
    DC
    FUGRO
    1940.0
    [m]
    DC
    FUGRO
    1970.0
    [m]
    DC
    FUGRO
    2000.0
    [m]
    DC
    FUGRO
    2030.0
    [m]
    DC
    FUGRO
    2060.0
    [m]
    DC
    FUGRO
    2090.0
    [m]
    DC
    FUGRO
    2120.0
    [m]
    DC
    FUGRO
    2150.0
    [m]
    DC
    FUGRO
    2180.0
    [m]
    DC
    FUGRO
    2210.0
    [m]
    DC
    FUGRO
    2240.0
    [m]
    DC
    FUGRO
    2270.0
    [m]
    DC
    FUGRO
    2300.0
    [m]
    DC
    FUGRO
    2330.0
    [m]
    DC
    FUGRO
    2360.0
    [m]
    DC
    FUGRO
    2390.0
    [m]
    DC
    FUGRO
    2420.0
    [m]
    DC
    FUGRO
    2450.0
    [m]
    DC
    FUGRO
    2480.0
    [m]
    DC
    FUGRO
    2510.0
    [m]
    DC
    FUGRO
    2520.0
    [m]
    DC
    FUGRO
    2530.0
    [m]
    DC
    FUGRO
    2540.0
    [m]
    DC
    FUGRO
    2560.0
    [m]
    DC
    FUGRO
    2570.0
    [m]
    DC
    FUGRO
    2580.0
    [m]
    DC
    FUGRO
    2590.0
    [m]
    DC
    FUGRO
    2600.0
    [m]
    DC
    FUGRO
    2610.0
    [m]
    DC
    FUGRO
    2620.0
    [m]
    DC
    FUGRO
    2630.0
    [m]
    DC
    FUGRO
    2640.0
    [m]
    DC
    FUGRO
    2650.0
    [m]
    DC
    FUGRO
    2660.0
    [m]
    DC
    FUGRO
    2670.0
    [m]
    DC
    FUGRO
    2690.0
    [m]
    DC
    FUGRO
    2700.0
    [m]
    DC
    FUGRO
    2720.0
    [m]
    DC
    FUGRO
    2730.0
    [m]
    DC
    FUGRO
    2740.0
    [m]
    DC
    FUGRO
    2750.0
    [m]
    DC
    FUGRO
    2760.0
    [m]
    DC
    FUGRO
    2770.0
    [m]
    DC
    FUGRO
    2780.0
    [m]
    DC
    FUGRO
    2790.0
    [m]
    DC
    FUGRO
    2797.0
    [m]
    DC
    FUGRO
    2810.0
    [m]
    DC
    FUGRO
    2820.0
    [m]
    DC
    FUGRO
    2826.0
    [m]
    DC
    FUGRO
    2829.0
    [m]
    DC
    FUGRO
    2832.0
    [m]
    DC
    FUGRO
    2841.0
    [m]
    DC
    FUGRO
    2852.0
    [m]
    DC
    FUGRO
    2856.0
    [m]
    DC
    FUGRO
    2858.0
    [m]
    DC
    FUGRO
    2865.0
    [m]
    DC
    FUGRO
    2869.0
    [m]
    DC
    FUGRO
    2874.0
    [m]
    DC
    FUGRO
    2879.0
    [m]
    DC
    FUGRO
    2883.0
    [m]
    DC
    FUGRO
    2891.0
    [m]
    DC
    FUGRO
    2897.0
    [m]
    DC
    FUGRO
    2905.0
    [m]
    DC
    FUGRO
    2910.0
    [m]
    DC
    FUGRO
    2911.0
    [m]
    DC
    FUGRO
    2917.0
    [m]
    DC
    FUGRO
    2919.0
    [m]
    DC
    FUGRO
    2925.0
    [m]
    DC
    FUGRO
    2928.0
    [m]
    DC
    FUGRO
    2937.0
    [m]
    DC
    FUGRO
    2943.0
    [m]
    DC
    FUGRO
    2949.0
    [m]
    DC
    FUGRO
    2955.0
    [m]
    DC
    FUGRO
    2964.0
    [m]
    DC
    FUGRO
    2970.0
    [m]
    DC
    FUGRO
    2973.0
    [m]
    DC
    FUGRO
    2979.0
    [m]
    DC
    FUGRO
    2982.0
    [m]
    DC
    FUGRO
    2988.0
    [m]
    DC
    FUGRO
    2993.0
    [m]
    DC
    FUGRO
    3000.0
    [m]
    DC
    FUGRO
    3006.0
    [m]
    DC
    FUGRO
    3012.0
    [m]
    DC
    FUGRO
    3016.0
    [m]
    DC
    FUGRO
    3024.0
    [m]
    DC
    FUGRO
    3030.0
    [m]
    DC
    FUGRO
    3036.0
    [m]
    DC
    FUGRO
    3044.5
    [m]
    DC
    FUGRO
    3045.0
    [m]
    DC
    FUGRO
    3054.0
    [m]
    DC
    FUGRO
    3062.0
    [m]
    DC
    FUGRO
    3066.0
    [m]
    DC
    FUGRO
    3072.0
    [m]
    DC
    FUGRO
    3078.0
    [m]
    DC
    FUGRO
    3084.0
    [m]
    DC
    FUGRO
    3091.0
    [m]
    DC
    FUGRO
    3096.0
    [m]
    DC
    FUGRO
    3102.0
    [m]
    DC
    FUGRO
    3108.0
    [m]
    DC
    FUGRO
    3114.0
    [m]
    DC
    FUGRO
    3123.0
    [m]
    DC
    FUGRO
    3132.0
    [m]
    DC
    FUGRO
    3144.0
    [m]
    DC
    FUGRO
    3150.0
    [m]
    DC
    FUGRO
    3156.0
    [m]
    DC
    FUGRO
    3162.0
    [m]
    DC
    FUGRO
    3168.0
    [m]
    DC
    FUGRO
    3174.0
    [m]
    DC
    FUGRO
    3180.0
    [m]
    DC
    FUGRO
    3186.0
    [m]
    DC
    FUGRO
    3192.0
    [m]
    DC
    FUGRO
    3198.0
    [m]
    DC
    FUGRO
    3204.0
    [m]
    DC
    FUGRO
    3210.0
    [m]
    DC
    FUGRO
    3216.0
    [m]
    DC
    FUGRO
    3222.0
    [m]
    DC
    FUGRO
    3228.0
    [m]
    DC
    FUGRO
    3234.0
    [m]
    DC
    FUGRO
    3240.0
    [m]
    DC
    FUGRO
  • Oil samples at the Norwegian Offshore Directorate

    Oil samples at the Norwegian Offshore Directorate
    Test type
    Bottle number
    Top depth
    MD [m]
    Bottom depth
    MD [m]
    Fluid type
    Test time
    Samples available
    MDT
    2941.00
    0.00
    OIL
    10.05.2007 - 05:38
    YES
  • Lithostratigraphy

  • 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
    467.0
    36
    470.0
    0.00
    LOT
    SURF.COND.
    20
    528.0
    26
    530.0
    1.25
    LOT
    INTERM.
    13 3/8
    1675.0
    17 1/2
    1680.0
    1.31
    LOT
    INTERM.
    9 5/8
    2821.0
    12 1/4
    2825.0
    1.74
    LOT
    OPEN HOLE
    3203.0
    8 1/2
    3203.0
    0.00
    LOT
  • Drilling mud

    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    701
    1.17
    16.0
    WATER BASED
    1190
    1.25
    24.0
    WATER BASED
    1657
    1.26
    24.0
    WATER BASED
    1681
    1.28
    23.0
    WATER BASED
    2068
    1.24
    30.0
    WATER BASED
    2163
    1.25
    28.0
    WATER BASED
    2285
    1.25
    28.0
    WATER BASED
    2415
    1.32
    21.0
    WATER BASED
    2619
    1.32
    23.0
    WATER BASED
    2847
    1.24
    25.0
    WATER BASED
    2980
    1.24
    26.0
    WATER BASED
    3013
    1.24
    28.0
    WATER BASED
    3240
    1.24
    24.0
    WATER BASED
    3250
    1.25
    19.0
    WATER BASED