Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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22.11.2024 - 09:09
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35/11-14 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.
    35/11-14 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).
    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.
    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.
    35/11-14
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    Seismic survey MN-9201R05-NE inline 937-crossline 1076
    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 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.
    1119-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.
    107
    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,
    23.08.2006
    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.
    07.12.2006
    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.
    07.12.2008
    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.
    18.12.2008
    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.
    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.
    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.
    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.
    361.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3306.0
    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).
    3285.5
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    16.5
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    122
    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 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° 9' 2.41'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    3° 32' 51.76'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6779854.28
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    529484.24
    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.
    5365

  • Wellbore history
    General
    Well 35/11-14 S is an appraisal well on the B-segment of the Astero discovery in PL090B. The Astero prospect is located north of the Fram West field, in the northern part of the 35/11-block. The target was Intra Heather Formation turbidite sandstones of Middle Oxfordian age derived from the Sognefjord delta in the East. The primary objectives were to test the presence and type of hydrocarbons in the Oxfordian sands, and assess reservoir quality, hydrocarbon column heights and regional pressure communication. Samples of all fluids were to be obtained. The TD criterion was to drill 100 m below base of the Intra Heather Formation reservoir section.
    Operations and results
    Well 35/11-14 S was spudded with the semi-submersible installation Transocean Winner on 23 August 2006 and drilled to TD at 3306 m (3285.6 m TVD RKB) in the Late Jurassic Heather Formation. After drilling into Pliocene sands at 693 m the well started to flow. The well was then displaced to 1.5 SG kill mud. It was discovered that mud motor and 26" bit had been twisted off and left in the hole. The well was cemented back to 30" casing shoe and technically side tracked from 500 m. A new 26" section was drilled to 641 m. The well was drilled as a deviated hole, but close to vertical through the reservoir section. It was drilled with spud mud down to 640 m and with Glydril (2 - 4.5% glycol) from 640 m to TD.
    The well was drilled within the fault bounded dip closure, shallow on the structure. The Intra Heather Formation sands (Oxfordian turbidites) were encountered as prognosed at 3103 - 3215 m (3083 - 3195 m TVD RKB). They contained commercial hydrocarbons with a gas oil contact at 3106.5 m (3086.5 m TVD RKB), and an oil water contact (Free Water Level) at 3126.0 m (3106 m TVD RKB). Good oil shows were observed down to 3158 m.
    Two cores were cut from 3110 to 3164 m. They comprised mainly sandstones with occasional thin siltstones. The reservoir was logged on wire line. MDT fluid samples were taken at three depths. Water samples were obtained at 3144 m, and at this level a formation temperature of 118 deg C was recorded. Oil samples were taken at 3120.5 m, while condensate samples were taken at 3105.5 m.
    The well was permanently plugged and abandoned on 7 December 2006 as an oil and gas appraisal.
    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]
    650.00
    3300.00

  • 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
    3110.0
    3136.5
    [m ]
    2
    3137.0
    3163.8
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    53.3
    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
    1060.0
    [m]
    DC
    FUGRO
    1090.0
    [m]
    DC
    FUGRO
    1120.0
    [m]
    DC
    FUGRO
    1150.0
    [m]
    DC
    FUGRO
    1180.0
    [m]
    DC
    FUGRO
    1210.0
    [m]
    DC
    FUGRO
    1240.0
    [m]
    DC
    FUGRO
    1270.0
    [m]
    DC
    FUGRO
    1300.0
    [m]
    DC
    FUGRO
    1330.0
    [m]
    DC
    FUGRO
    1360.0
    [m]
    DC
    FUGRO
    1390.0
    [m]
    DC
    FUGRO
    1420.0
    [m]
    DC
    FUGRO
    1450.0
    [m]
    DC
    FUGRO
    1480.0
    [m]
    DC
    FUGRO
    1510.0
    [m]
    DC
    FUGRO
    1540.0
    [m]
    DC
    FUGRO
    1570.0
    [m]
    DC
    FUGRO
    1600.0
    [m]
    DC
    FUGRO
    1630.0
    [m]
    DC
    FUGRO
    1660.0
    [m]
    DC
    FUGRO
    1700.0
    [m]
    DC
    FUGRO
    1730.0
    [m]
    DC
    FUGRO
    1760.0
    [m]
    DC
    FUGRO
    1790.0
    [m]
    DC
    FUGRO
    1810.0
    [m]
    DC
    FUGRO
    1840.0
    [m]
    DC
    FUGRO
    1860.0
    [m]
    DC
    FUGRO
    1890.0
    [m]
    DC
    FUGRO
    1920.0
    [m]
    DC
    FUGRO
    1950.0
    [m]
    DC
    FUGRO
    1970.0
    [m]
    DC
    FUGRO
    1990.0
    [m]
    DC
    FUGRO
    2010.0
    [m]
    DC
    FUGRO
    2030.0
    [m]
    DC
    FUGRO
    2050.0
    [m]
    DC
    FUGRO
    2070.0
    [m]
    DC
    FUGRO
    2090.0
    [m]
    DC
    FUGRO
    2110.0
    [m]
    DC
    FUGRO
    2130.0
    [m]
    DC
    FUGRO
    2150.0
    [m]
    DC
    FUGRO
    2180.0
    [m]
    DC
    FUGRO
    2210.0
    [m]
    DC
    FUGRO
    2230.0
    [m]
    DC
    FUGRO
    2250.0
    [m]
    DC
    FUGRO
    2270.0
    [m]
    DC
    FUGRO
    2995.0
    [m]
    DC
    FUGRO
    3001.0
    [m]
    DC
    FUGRO
    3007.0
    [m]
    DC
    FUGRO
    3010.0
    [m]
    DC
    FUGRO
    3013.0
    [m]
    DC
    FUGRO
    3016.0
    [m]
    DC
    FUGRO
    3019.0
    [m]
    DC
    FUGRO
    3022.0
    [m]
    DC
    FUGRO
    3025.0
    [m]
    DC
    FUGRO
    3028.0
    [m]
    DC
    FUGRO
    3031.0
    [m]
    DC
    FUGRO
    3034.0
    [m]
    DC
    FUGRO
    3037.0
    [m]
    DC
    FUGRO
    3040.0
    [m]
    DC
    FUGRO
    3043.0
    [m]
    DC
    FUGRO
    3046.0
    [m]
    DC
    FUGRO
    3049.0
    [m]
    DC
    FUGRO
    3052.0
    [m]
    DC
    FUGRO
    3055.0
    [m]
    DC
    FUGRO
    3058.0
    [m]
    DC
    FUGRO
    3061.0
    [m]
    DC
    FUGRO
    3064.0
    [m]
    DC
    FUGRO
    3067.0
    [m]
    DC
    FUGRO
    3073.0
    [m]
    DC
    FUGRO
    3079.0
    [m]
    DC
    FUGRO
    3085.0
    [m]
    DC
    FUGRO
    3091.0
    [m]
    DC
    FUGRO
    3097.0
    [m]
    DC
    FUGRO
    3103.0
    [m]
    DC
    FUGRO
    3112.0
    [m]
    DC
    FUGRO
    3112.5
    [m]
    DC
    FUGRO
    3112.9
    [m]
    DC
    FUGRO
    3113.1
    [m]
    DC
    FUGRO
    3113.4
    [m]
    DC
    FUGRO
    3124.3
    [m]
    DC
    FUGRO
    3124.3
    [m]
    DC
    FUGRO
    3124.4
    [m]
    DC
    FUGRO
    3126.2
    [m]
    DC
    FUGRO
    3126.5
    [m]
    DC
    FUGRO
    3126.5
    [m]
    DC
    FUGRO
    3135.1
    [m]
    DC
    FUGRO
    3144.3
    [m]
    DC
    FUGRO
    3144.4
    [m]
    DC
    FUGRO
    3146.4
    [m]
    DC
    FUGRO
    3146.9
    [m]
    DC
    FUGRO
    3147.0
    [m]
    DC
    FUGRO
    3148.6
    [m]
    DC
    FUGRO
    3148.7
    [m]
    DC
    FUGRO
    3148.9
    [m]
    DC
    FUGRO
    3149.3
    [m]
    DC
    FUGRO
    3149.3
    [m]
    DC
    FUGRO
    3150.4
    [m]
    DC
    FUGRO
    3150.5
    [m]
    DC
    FUGRO
    3150.5
    [m]
    DC
    FUGRO
    3152.0
    [m]
    DC
    FUGRO
    3154.3
    [m]
    DC
    FUGRO
    3154.5
    [m]
    DC
    FUGRO
    3154.6
    [m]
    DC
    FUGRO
    3154.8
    [m]
    DC
    FUGRO
    3155.5
    [m]
    DC
    FUGRO
    3156.1
    [m]
    DC
    FUGRO
    3156.4
    [m]
    DC
    FUGRO
    3156.4
    [m]
    DC
    FUGRO
    3156.5
    [m]
    DC
    FUGRO
    3156.6
    [m]
    DC
    FUGRO
    3163.0
    [m]
    DC
    FUGRO
    3163.8
    [m]
    DC
    FUGRO
    3169.0
    [m]
    DC
    FUGRO
    3175.0
    [m]
    DC
    FUGRO
    3181.0
    [m]
    DC
    FUGRO
    3187.0
    [m]
    DC
    FUGRO
    3193.0
    [m]
    DC
    FUGRO
    3199.0
    [m]
    DC
    FUGRO
    3205.0
    [m]
    DC
    FUGRO
    3211.0
    [m]
    DC
    FUGRO
    3217.0
    [m]
    DC
    FUGRO
    3223.0
    [m]
    DC
    FUGRO
    3229.0
    [m]
    DC
    FUGRO
    3235.0
    [m]
    DC
    FUGRO
    3241.0
    [m]
    DC
    FUGRO
    3244.0
    [m]
    DC
    FUGRO
    3247.0
    [m]
    DC
    FUGRO
    3250.0
    [m]
    DC
    FUGRO
    3253.0
    [m]
    DC
    FUGRO
    3256.0
    [m]
    DC
    FUGRO
    3259.0
    [m]
    DC
    FUGRO
    3265.0
    [m]
    DC
    FUGRO
    3271.0
    [m]
    DC
    FUGRO
    3277.0
    [m]
    DC
    FUGRO
    3286.0
    [m]
    DC
    FUGRO
    3292.0
    [m]
    DC
    FUGRO
    3298.0
    [m]
    DC
    FUGRO
    3301.0
    [m]
    DC
    FUGRO

  • Lithostratigraphy

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CMR CAL
    2740
    3240
    EMS SGT DTC LEH
    640
    1057
    MDT
    3104
    3250
    MDT DP VIT HC
    3105
    3141
    MWD LWD - DIR
    387
    468
    MWD LWD - DIR GR RES APWD
    468
    3306
    SPEA GPIT DSI HRLA PEX ECS CMR
    2700
    3307

  • 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
    385.0
    36
    387.0
    0.00
    LOT
    SURF.COND.
    20
    465.0
    26
    468.0
    0.00
    LOT
    INTERM.
    13 3/8
    1671.0
    17
    1679.0
    1.26
    LOT
    INTERM.
    9 5/8
    2831.0
    12 1/4
    2833.0
    1.63
    LOT
    OPEN HOLE
    3306.0
    8 1/2
    3306.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    622
    1.20
    15.0
    WATER BASED
    640
    1.20
    17.0
    WATER BASED
    1050
    1.20
    15.0
    WATER BASED
    1058
    1.20
    18.0
    WATER BASED
    1193
    1.26
    21.0
    WATER BASED
    1390
    1.29
    20.0
    WATER BASED
    1679
    1.29
    17.0
    WATER BASED
    1757
    1.31
    17.0
    WATER BASED
    2400
    1.31
    18.0
    WATER BASED
    2829
    1.34
    21.0
    WATER BASED